Consolidated Edison Co Of New York 10-K 17 Feb 22 2021 FY Annual report Financial data

Cover Page

Cover Page - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2021	Jan. 31, 2022	Jun. 30, 2021
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	1-14514
Entity Registrant Name	Consolidated Edison, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-3965100
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Title of 12(b) Security	Common Shares ($.10 par value)
Trading Symbol	ED
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 25.3
Entity Common Stock, Shares Outstanding		354,090,402
Amendment Flag	false
Document Fiscal Year Focus	2021
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Entity Central Index Key	0001047862
Documents Incorporated by Reference	Documents Incorporated By Reference Portions of Con Edison’s definitive proxy statement for its Annual Meeting of Stockholders to be held on May 16, 2022, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2021, is incorporated in Part III of this report.
CECONY
Document Information [Line Items]
Entity File Number	1-1217
Entity Registrant Name	Consolidated Edison Company of New York, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-5009340
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2021
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Entity Central Index Key	0000023632

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2021
Auditor Information [Abstract]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	New York, New York
Auditor Firm ID	238

Consolidated Income Statement

Consolidated Income Statement - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING REVENUES
Total operating revenues	$ 13,676	$ 12,246	$ 12,574
OPERATING EXPENSES
Depreciation and amortization	2,032	1,920	1,684
Taxes, other than income taxes	2,810	2,575	2,406
TOTAL OPERATING EXPENSES	10,850	9,592	9,898
OPERATING INCOME	2,826	2,654	2,676
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	(420)	(214)	96
Other income	22	23	45
Allowance for equity funds used during construction	21	17	14
Other deductions	(161)	(227)	(104)
TOTAL OTHER INCOME (DEDUCTIONS)	(538)	(401)	51
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,288	2,253	2,727
INTEREST EXPENSE
Interest on long-term debt	930	915	888
Other interest	(14)	118	116
Allowance for borrowed funds used during construction	(11)	(14)	(13)
NET INTEREST EXPENSE	905	1,019	991
INCOME BEFORE INCOME TAX EXPENSE	1,383	1,234	1,736
INCOME TAX EXPENSE	190	90	296
NET INCOME	1,193	1,144	1,440
(Loss) Income attributable to non-controlling interest	(153)	43	97
NET INCOME FOR COMMON STOCK	$ 1,346	$ 1,101	$ 1,343
Net income per common share — basic (in dollars per share)	$ 3.86	$ 3.29	$ 4.09
Net income per common share — diluted (in dollars per share)	$ 3.85	$ 3.28	$ 4.08
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (in shares)	348.4	334.8	328.5
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (in shares)	349.4	335.7	329.5
CECONY
OPERATING REVENUES
Total operating revenues	$ 11,716	$ 10,647	$ 10,821
OPERATING EXPENSES
Depreciation and amortization	1,705	1,598	1,373
Taxes, other than income taxes	2,696	2,456	2,295
TOTAL OPERATING EXPENSES	9,256	8,337	8,473
OPERATING INCOME	2,460	2,310	2,348
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	16	19	40
Allowance for equity funds used during construction	19	14	12
Other deductions	(143)	(204)	(87)
TOTAL OTHER INCOME (DEDUCTIONS)	(108)	(171)	(35)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,352	2,139	2,313
INTEREST EXPENSE
Interest on long-term debt	759	718	672
Other interest	13	33	67
Allowance for borrowed funds used during construction	(10)	(12)	(11)
NET INTEREST EXPENSE	762	739	728
INCOME BEFORE INCOME TAX EXPENSE	1,590	1,400	1,585
INCOME TAX EXPENSE	246	215	335
NET INCOME FOR COMMON STOCK	1,344	1,185	1,250
Electric
OPERATING REVENUES
Total operating revenues	9,485	8,730	8,694
Electric | CECONY
OPERATING REVENUES
Total operating revenues	8,806	8,103	8,062
Gas
OPERATING REVENUES
Total operating revenues	2,638	2,269	2,391
OPERATING EXPENSES
Operating costs	690	527	880
Gas | CECONY
OPERATING REVENUES
Total operating revenues	2,378	2,036	2,132
OPERATING EXPENSES
Operating costs	541	426	606
Steam
OPERATING REVENUES
Total operating revenues	532	508	627
Steam | CECONY
OPERATING REVENUES
Total operating revenues	532	508	627
Non-utility
OPERATING REVENUES
Total operating revenues	1,021	739	862
Purchased power
OPERATING EXPENSES
Operating costs	1,835	1,600	1,546
Purchased power | CECONY
OPERATING EXPENSES
Operating costs	1,633	1,432	1,357
Fuel
OPERATING EXPENSES
Operating costs	229	156	207
Fuel | CECONY
OPERATING EXPENSES
Operating costs	229	156	207
Other operations and maintenance
OPERATING EXPENSES
Operating costs	3,254	2,814	3,175
Other operations and maintenance | CECONY
OPERATING EXPENSES
Operating costs	$ 2,452	$ 2,269	$ 2,635

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ 1,346	$ 1,101	$ 1,343
Net Income	1,193	1,144	1,440
LOSS (INCOME) ATTRIBUTABLE TO NON-CONTROLLING INTEREST	153	(43)	(97)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	30	(6)	(5)
Other income, net of taxes	0	0	2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	30	(6)	(3)
COMPREHENSIVE INCOME	1,376	1,095	1,340
CECONY
Net income	1,344	1,185	1,250
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	7	(1)	(3)
Other income, net of taxes	0	0	2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	7	(1)	(1)
COMPREHENSIVE INCOME	$ 1,351	$ 1,184	$ 1,249

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING ACTIVITIES
Net Income	$ 1,193	$ 1,144	$ 1,440
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	2,032	1,920	1,684
Impairment of assets	443	320	0
Deferred income taxes	133	85	308
Rate case amortization and accruals	(16)	(40)	(116)
Common equity component of allowance for funds used during construction	(21)	(17)	(14)
Net derivative (gains)/losses	(53)	57	27
Gain on Sale of Assets	0	0	(14)
Unbilled revenue and net unbilled revenue deferrals	(53)	(1)	(3)
Other non-cash items, net	148	49	(26)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(411)	(543)	23
Reserve adjustments	169	78	8
Materials and supplies, including fuel oil and gas in storage	(82)	(4)	6
Revenue decoupling mechanism receivable	(53)	(61)	(76)
Other receivables and other current assets	(103)	(134)	54
Taxes receivable	13	(6)	29
Prepayments	(24)	(11)	(73)
Accounts payable	44	170	10
Pensions and retiree benefits obligations, net	266	285	357
Pensions and retiree benefits contributions	(472)	(478)	(357)
Accrued taxes	(46)	74	10
Accrued interest	4	(4)	24
Superfund and environmental remediation costs	(10)	(22)	(9)
Distributions from equity investments	18	39	57
System benefit charge	(34)	(119)	20
Deferred charges, noncurrent assets and other regulatory assets	(563)	(653)	(492)
Deferred credits and other regulatory liabilities	175	10	278
Other current and noncurrent liabilities	36	60	(21)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,733	2,198	3,134
INVESTING ACTIVITIES
Utility construction expenditures	(3,630)	(3,326)	(3,238)
Cost of removal less salvage	(323)	(310)	(295)
Non-utility construction expenditures	(323)	(583)	(248)
Proceeds from sale of assets	629	0	192
Other investing activities	10	22	22
Net (payment)/issuance of short-term debt	(382)	178	(874)
Divestiture of renewable electric projects	183	0	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,484)	(4,224)	(3,782)
FINANCING ACTIVITIES
Issuance of long-term debt	2,804	2,925	3,017
Retirement of long-term debt	(1,960)	(518)	(1,195)
Debt issuance costs	(40)	(47)	(32)
Common stock dividends	(1,030)	(975)	(924)
Issuance of common shares - public offering	775	640	825
Issuance of common shares for stock plans	60	58	54
Distribution to noncontrolling interest	(23)	(16)	(12)
Proceeds from Other Equity	257	0	0
NET CASH FLOWS FROM FINANCING ACTIVITIES	461	2,245	859
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(290)	219	211
BALANCE AT BEGINNING OF PERIOD	1,436	1,217	1,006
BALANCE AT END OF PERIOD	1,146	1,436	1,217
Cash paid/(received) during the period for:
Interest	924	920	876
Income taxes	9	38	(26)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	457	478	336
Issuance of common shares for dividend reinvestment	49	48	47
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(30)	(3)	(205)
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	0	(24)	(10)
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	23	51	80
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 22	$ 28	$ 33

Consolidated Statement of Cas_2

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING ACTIVITIES
Net income	$ 1,346	$ 1,101	$ 1,343
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	2,032	1,920	1,684
Deferred income taxes	133	85	308
Rate case amortization and accruals	(16)	(40)	(116)
Common equity component of allowance for funds used during construction	(21)	(17)	(14)
Gain on Sale of Assets	0	0	(14)
Unbilled revenue and net unbilled revenue deferrals	(53)	(1)	(3)
Other non-cash items, net	148	49	(26)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(411)	(543)	23
Reserve adjustments	169	78	8
Materials and supplies, including fuel oil and gas in storage	(82)	(4)	6
Revenue decoupling mechanism receivable	(53)	(61)	(76)
Other receivables and other current assets	(103)	(134)	54
Prepayments	(24)	(11)	(73)
Accounts payable	44	170	10
Pensions and retiree benefits obligations, net	266	285	357
Pensions and retiree benefits contributions	(472)	(478)	(357)
Superfund and environmental remediation costs	(10)	(22)	(9)
Accrued taxes	(46)	74	10
Accrued interest	4	(4)	24
System benefit charge	(34)	(119)	20
Deferred charges, noncurrent assets and other regulatory assets	(563)	(653)	(492)
Deferred credits and other regulatory liabilities	175	10	278
Other current and noncurrent liabilities	36	60	(21)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,733	2,198	3,134
INVESTING ACTIVITIES
Utility construction expenditures	(3,630)	(3,326)	(3,238)
Cost of removal less salvage	(323)	(310)	(295)
Proceeds from sale of assets	629	0	192
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,484)	(4,224)	(3,782)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(382)	178	(874)
Issuance of long-term debt	2,804	2,925	3,017
Retirement of long-term debt	(1,960)	(518)	(1,195)
Debt issuance costs	(40)	(47)	(32)
NET CASH FLOWS FROM FINANCING ACTIVITIES	461	2,245	859
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(290)	219	211
BALANCE AT BEGINNING OF PERIOD	1,436	1,217	1,006
BALANCE AT END OF PERIOD	1,146	1,436	1,217
Cash paid/(received) during the period for:
Interest	924	920	876
Income taxes	9	38	(26)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	457	478	336
CECONY
OPERATING ACTIVITIES
Net income	1,344	1,185	1,250
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,705	1,598	1,373
Deferred income taxes	124	168	128
Rate case amortization and accruals	(16)	(40)	(117)
Common equity component of allowance for funds used during construction	(19)	(14)	(12)
Gain on Sale of Assets	0	0	(14)
Unbilled revenue and net unbilled revenue deferrals	(16)	(47)	(3)
Other non-cash items, net	33	(8)	0
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(412)	(516)	3
Reserve adjustments	166	74	7
Materials and supplies, including fuel oil and gas in storage	(78)	2	11
Revenue decoupling mechanism receivable	(62)	(53)	(76)
Other receivables and other current assets	(85)	(49)	54
Accounts receivables from affiliated companies	96	(61)	141
Prepayments	(53)	19	(61)
Accounts payable	65	145	(7)
Accounts payable to affiliated companies	(4)	9	(4)
Pensions and retiree benefits obligations, net	283	253	330
Pensions and retiree benefits contributions	(433)	(438)	(325)
Superfund and environmental remediation costs	(18)	(30)	(12)
Accrued taxes	(54)	61	11
Accrued taxes to affiliated companies	9	1	0
Accrued interest	1	13	1
System benefit charge	(32)	(112)	18
Deferred charges, noncurrent assets and other regulatory assets	(544)	(603)	(486)
Deferred credits and other regulatory liabilities	128	92	306
Other current and noncurrent liabilities	58	44	(14)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,186	1,693	2,502
INVESTING ACTIVITIES
Utility construction expenditures	(3,413)	(3,112)	(3,028)
Cost of removal less salvage	(316)	(304)	(288)
Proceeds from sale of assets	0	0	192
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,729)	(3,416)	(3,124)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(299)	523	(55)
Issuance of long-term debt	2,250	2,200	1,300
Retirement of long-term debt	(640)	(350)	(475)
Debt issuance costs	(27)	(34)	(21)
Capital contribution by parent	1,100	500	900
Dividend to parent	(988)	(982)	(912)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,396	1,857	737
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(147)	134	115
BALANCE AT BEGINNING OF PERIOD	1,067	933	818
BALANCE AT END OF PERIOD	920	1,067	933
Cash paid/(received) during the period for:
Interest	739	693	676
Income taxes	5	102	73
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	406	417	285
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	23	51	80
Software Licenses | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	22	48	76
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	22	28	33
Equipment | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 22	$ 28	$ 33

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
CURRENT ASSETS
Cash and temporary cash investments	$ 992	$ 1,272
Accounts receivable - customers, less allowance for uncollectible accounts	1,943	1,701
Other receivables, less allowance for uncollectible accounts	298	278
Taxes receivable	13	26
Accrued unbilled revenue	662	599
Fuel oil, gas in storage, materials and supplies, at average cost	437	356
Prepayments	295	271
Regulatory assets	206	266
Restricted cash	154	164
Revenue decoupling mechanism receivable	190	137
Other current assets	361	231
TOTAL CURRENT ASSETS	5,551	5,301
INVESTMENTS	853	1,816
UTILITY PLANT, AT ORIGINAL COST
General	4,170	3,880
TOTAL	54,239	50,738
Less: Accumulated depreciation	12,177	11,188
Net	42,062	39,550
Construction work in progress	2,152	2,474
NET UTILITY PLANT	44,214	42,024
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4,194	3,893
Construction work in progress	188	638
NET PLANT	48,596	46,555
OTHER NONCURRENT ASSETS
Goodwill	439	446
Intangible assets, net of accumulated amortization of $297 and $228 in 2021 and 2020, respectively	1,293	1,460
Operating lease right-of-use-asset	809	837
Regulatory assets	3,639	6,195
Pension and Retiree Benefits	1,654	0
Other deferred charges and noncurrent assets	282	285
TOTAL OTHER NONCURRENT ASSETS	8,116	9,223
TOTAL ASSETS	63,116	62,895
CURRENT LIABILITIES
Long-term debt due within one year	440	1,967
Term Loan	0	165
Notes payable	1,488	1,705
Accounts payable	1,497	1,475
Customer deposits	300	311
Accrued taxes	104	150
Accrued interest	151	149
Accrued wages	113	108
Fair value of derivative liabilities	152	238
Regulatory liabilities	185	36
System benefit charge	423	528
Operating lease liabilities	113	96
Other current liabilities	461	426
TOTAL CURRENT LIABILITIES	5,427	7,354
NONCURRENT LIABILITIES
Provision for injuries and damages	183	178
Pensions and retiree benefits	737	2,257
Superfund and other environmental costs	940	857
Asset retirement obligations	577	576
Fair value of derivative liabilities	84	240
Deferred income taxes and unamortized investment tax credits	6,873	6,475
Operating lease liabilities	717	764
Regulatory liabilities	4,381	4,513
Other deferred credits and noncurrent liabilities	257	234
TOTAL NONCURRENT LIABILITIES	14,749	16,094
LONG-TERM DEBT	22,604	20,382
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,037	18,847
Noncontrolling interest	299	218
TOTAL EQUITY (See Statement of Equity)	20,336	19,065
TOTAL LIABILITIES AND EQUITY	63,116	62,895
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	34,938	33,315
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	12,303	10,847
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,828	$ 2,696

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accounts receivable - customers, allowance for uncollectible accounts	$ 317	$ 148
Other receivables, allowance for uncollectible accounts	22	7
Non-utility property, accumulated depreciation	626	522
Intangible assets, accumulated amortization	297	228
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	304	138
Other receivables, allowance for uncollectible accounts	19	4
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Balance Sheet_2

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
CURRENT ASSETS
Cash and temporary cash investments	$ 992	$ 1,272
Accounts receivable - customers, less allowance for uncollectible accounts	1,943	1,701
Other receivables, less allowance for uncollectible accounts	298	278
Taxes receivable	13	26
Accrued unbilled revenue	662	599
Fuel oil, gas in storage, materials and supplies, at average cost	437	356
Prepayments	295	271
Regulatory assets	206	266
Revenue decoupling mechanism receivable	190	137
Other current assets	361	231
TOTAL CURRENT ASSETS	5,551	5,301
INVESTMENTS	853	1,816
UTILITY PLANT, AT ORIGINAL COST
General	4,170	3,880
TOTAL	54,239	50,738
Less: Accumulated depreciation	12,177	11,188
Net	42,062	39,550
Construction work in progress	2,152	2,474
NET UTILITY PLANT	44,214	42,024
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4,194	3,893
NET PLANT	48,596	46,555
OTHER NONCURRENT ASSETS
Regulatory assets	3,639	6,195
Operating lease right-of-use-asset	809	837
Pension and Retiree Benefits	1,654	0
Other deferred charges and noncurrent assets	282	285
TOTAL OTHER NONCURRENT ASSETS	8,116	9,223
TOTAL ASSETS	63,116	62,895
CURRENT LIABILITIES
Long-term debt due within one year	440	1,967
Notes payable	1,488	1,705
Accounts payable	1,497	1,475
Customer deposits	300	311
Accrued taxes	104	150
Accrued interest	151	149
Accrued wages	113	108
Fair value of derivative liabilities	152	238
Regulatory liabilities	185	36
System benefit charge	423	528
Operating lease liabilities	113	96
Other current liabilities	461	426
TOTAL CURRENT LIABILITIES	5,427	7,354
NONCURRENT LIABILITIES
Provision for injuries and damages	183	178
Pensions and retiree benefits	737	2,257
Superfund and other environmental costs	940	857
Asset retirement obligations	577	576
Fair value of derivative liabilities	84	240
Deferred income taxes and unamortized investment tax credits	6,873	6,475
Operating lease liabilities	717	764
Regulatory liabilities	4,381	4,513
Other deferred credits and noncurrent liabilities	257	234
TOTAL NONCURRENT LIABILITIES	14,749	16,094
LONG-TERM DEBT	22,604	20,382
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,037	18,847
TOTAL LIABILITIES AND EQUITY	63,116	62,895
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	34,938	33,315
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	12,303	10,847
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,828	2,696
CECONY
CURRENT ASSETS
Cash and temporary cash investments	920	1,067
Accounts receivable - customers, less allowance for uncollectible accounts	1,841	1,595
Other receivables, less allowance for uncollectible accounts	121	134
Taxes receivable	5	8
Accrued unbilled revenue	549	523
Accounts receivable from affiliated companies	38	134
Fuel oil, gas in storage, materials and supplies, at average cost	369	291
Prepayments	212	159
Regulatory assets	188	244
Revenue decoupling mechanism receivable	191	129
Other current assets	269	123
TOTAL CURRENT ASSETS	4,703	4,407
INVESTMENTS	608	541
UTILITY PLANT, AT ORIGINAL COST
General	3,854	3,585
TOTAL	50,849	47,529
Less: Accumulated depreciation	11,223	10,297
Net	39,626	37,232
Construction work in progress	1,985	2,320
NET UTILITY PLANT	41,611	39,552
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	2	2
NET PLANT	41,613	39,554
OTHER NONCURRENT ASSETS
Regulatory assets	3,316	5,745
Operating lease right-of-use-asset	545	578
Pension and Retiree Benefits	1,677	0
Other deferred charges and noncurrent assets	193	142
TOTAL OTHER NONCURRENT ASSETS	5,731	6,465
TOTAL ASSETS	52,655	50,967
CURRENT LIABILITIES
Long-term debt due within one year	0	640
Notes payable	1,361	1,660
Accounts payable	1,285	1,232
Accounts payable to affiliated companies	18	22
Customer deposits	285	296
Accrued taxes	78	132
Accrued taxes to affiliated companies	10	1
Accrued interest	127	126
Accrued wages	103	97
Fair value of derivative liabilities	88	163
Regulatory liabilities	134	11
System benefit charge	372	475
Operating lease liabilities	90	73
Other current liabilities	370	319
TOTAL CURRENT LIABILITIES	4,321	5,247
NONCURRENT LIABILITIES
Provision for injuries and damages	178	172
Pensions and retiree benefits	669	1,943
Superfund and other environmental costs	850	780
Asset retirement obligations	504	508
Fair value of derivative liabilities	40	105
Deferred income taxes and unamortized investment tax credits	6,796	6,411
Operating lease liabilities	462	512
Regulatory liabilities	3,921	4,094
Other deferred credits and noncurrent liabilities	220	197
TOTAL NONCURRENT LIABILITIES	13,640	14,722
LONG-TERM DEBT	18,382	16,149
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	16,312	14,849
TOTAL LIABILITIES AND EQUITY	52,655	50,967
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	32,846	31,327
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	11,321	9,921
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,828	$ 2,696

Consolidated Balance Sheet (P_2

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accounts receivable - customers, allowance for uncollectible accounts	$ 317	$ 148
Other receivables, allowance for uncollectible accounts	22	7
Non-utility property, accumulated depreciation	626	522
Intangible assets, accumulated amortization	297	228
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	304	138
Other receivables, allowance for uncollectible accounts	19	4
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Equit

Consolidated Statement of Equity - USD ($) $ in Millions	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling Interest	CECONY	CECONYCommon Stock	CECONYAdditional Paid-In Capital	CECONYRetained Earnings	CECONYRepurchased Con Edison Stock	CECONYCapital Stock Expense	CECONYAccumulated Other Comprehensive Income/(Loss)
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2018		321,000,000								235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2018	$ 16,839	$ 34	$ 7,117	$ 10,728	$ (1,038)	$ (99)	$ (16)	$ 113
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2018									$ 12,910	$ 589	$ 4,769	$ 8,581	$ (962)	$ (62)	$ (5)
TREASURY STOCK, BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2018					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,343								1,250			1,250
Net Income	1,440			1,343				97
Common stock dividends	(971)			(971)					(912)			(912)
Issuance of common shares - public offering (in shares)		12,000,000
Issuance of common shares - public offering	825	$ 1	835			(11)
Issuance of common shares for stock plans	102		102
Capital contribution by parent									900		900
Other comprehensive income	(3)						(3)		(1)						(1)
Noncontrolling interest	(19)							(19)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019		333,000,000								235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2019	18,213	$ 35	8,054	11,100	$ (1,038)	(110)	(19)	191
BALANCE AS OF END OF PERIOD at Dec. 31, 2019									14,147	$ 589	5,669	8,919	(962)	(62)	(6)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,101								1,185			1,185
Net Income	1,144			1,101				43
Common stock dividends	(1,023)			(1,023)					(982)			(982)
Issuance of common shares - public offering (in shares)		9,000,000
Issuance of common shares - public offering	640	$ 1	641			(2)
Issuance of common shares for stock plans	113		113
Capital contribution by parent									500		500
Other comprehensive income	(6)						(6)		$ (1)						(1)
Noncontrolling interest	$ (16)							(16)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020	342,297,534	342,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	$ 19,065	$ 36	8,808	11,178	$ (1,038)	(112)	(25)	218
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	18,847								$ 14,849	$ 589	6,169	9,122	(962)	(62)	(7)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,346								1,344			1,344
Net Income	1,193			1,346				(153)
Common stock dividends	(1,079)			(1,079)					(988)			(988)
Issuance of common shares - public offering (in shares)		10,000,000
Issuance of common shares - public offering	766	$ 1	775			(10)
Issuance of common shares for stock plans	127		127
Capital contribution by parent									1,100		1,100
Other comprehensive income	30						30		$ 7						7
Distributions to noncontrolling interests	(23)							(23)
Net proceeds from sale of equity interest	$ 257							257
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2021	353,983,712	354,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2021	$ 20,336	$ 37	$ 9,710	$ 11,445	$ (1,038)	$ (122)	$ 5	$ 299
BALANCE AS OF END OF PERIOD at Dec. 31, 2021	$ 20,037								$ 16,312	$ 589	$ 7,269	$ 9,478	$ (962)	$ (62)	$ 0
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2021					23,000,000

Consolidated Statement of Equ_2

Consolidated Statement of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (in dollars per share)	$ 3.10	$ 3.06	$ 2.96

Consolidated Statement of Capit

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	354	342
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 20,032	$ 18,872
Pension plan liability adjustments, net of taxes	7	(23)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(2)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	5	(25)
Equity	20,037	18,847
Noncontrolling interest	299	218
TOTAL EQUITY (See Statement of Equity)	$ 20,336	$ 19,065
CECONY
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 16,312	$ 14,856
Pension plan liability adjustments, net of taxes	1	(5)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(1)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	0	(7)
Equity	16,312	14,849
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 16,312	$ 14,849

Consolidated Statement of Cap_2

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Schedule of Capitalization, Long-term Debt [Line Items]
Other long-term debt		$ 293	$ 971
Unamortized debt expense		(177)	(168)
Unamortized debt discount		(49)	(47)
TOTAL		23,044	22,349
Less: Long-term debt due within one year			1,967
TOTAL LONG-TERM DEBT		22,604	20,382
TOTAL CAPITALIZATION		42,641	39,229
CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Unamortized debt expense		(145)	(130)
Unamortized debt discount		(48)	(46)
TOTAL		18,382	16,789
Less: Long-term debt due within one year			640
TOTAL LONG-TERM DEBT		18,382	16,149
TOTAL CAPITALIZATION		$ 34,694	30,998
Copper Mountain Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	4.07%
TOTAL PROJECT DEBT	[1]	$ 192	204
Coram
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 0	141
Coram | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.77%
Coram | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.52%
Copper Mountain Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	4.12%
TOTAL PROJECT DEBT	[1]	$ 247	264
CED Southwest
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	3.72%
TOTAL PROJECT DEBT	[1]	$ 418	437
Wind Holdings
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.41%
TOTAL PROJECT DEBT		$ 95	109
Copper Mountain Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	3.42%
TOTAL PROJECT DEBT	[1]	$ 49	56
CED California Texas
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	3.39%
TOTAL PROJECT DEBT	[1]	$ 248	0
Mesquite Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 165	180
Mesquite Solar 1 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.24%
Mesquite Solar 1 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.03%
Texas Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 52	54
Texas Solar 4 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
Texas Solar 4 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
California Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.94%
TOTAL PROJECT DEBT		$ 88	93
California Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.07%
TOTAL PROJECT DEBT		$ 79	82
California Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.78%
TOTAL PROJECT DEBT		$ 171	178
California Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.82%
TOTAL PROJECT DEBT		$ 271	284
Broken Bow II
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.82%
TOTAL PROJECT DEBT		$ 65	67
Texas Solar 5
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.53%
TOTAL PROJECT DEBT		$ 135	140
Texas Solar 7
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.21%
TOTAL PROJECT DEBT		$ 184	192
Upton County Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL PROJECT DEBT		$ 83	87
CED Nevada Virginia
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.77%
TOTAL PROJECT DEBT		$ 228	0
Other project debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		7	10
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		2,777	2,578
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		19,750	18,565
Debentures | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 18,125	16,515
Debentures | Debenture Series 2016A, 2.00% Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.00%
TOTAL		$ 0	500
Debentures | Debenture 2018C, 0.65 Percent, Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.60%
TOTAL		$ 0	640
Debentures | Debenture 2020A, 0.65 Percent, Due 2023
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 650	650
Debentures | Debenture 2014B, 3.30 Percent, Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	250
Debentures | Debenture 2014B, 3.30 Percent, Due 2024 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	250
Debentures | Debenture Series 2016B, 2.90% Due 2026
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures | Debenture Series 2016B, 2.90% Due 2026 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures | Debenture Series 1997F, 6.50% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.50%
TOTAL		$ 80	80
Debentures | Debenture Series 2017B, 3.125% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures | Debenture Series 2017B, 3.125% Due 2027 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures | Debenture Series 2018A, 3.80% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.80%
TOTAL		$ 300	300
Debentures | Debenture Series 2018A, 3.80% Due 2028 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.80%
TOTAL		$ 300	300
Debentures | Debenture Series 2018D, 4.00% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 500	500
Debentures | Debenture Series 2018D, 4.00% Due 2028 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 500	500
Debentures | Debenture 2019B, 2.94 Percent, Due 2029
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.94%
TOTAL		$ 44	44
Debentures | Debenture 2020A, 3.35 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	600
Debentures | Debenture 2020A, 3.35 Percent, Due 2030 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	600
Debentures | Debenture 2020A, 2.02 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.02%
TOTAL		$ 35	35
Debentures | Debenture 2021A, 2.40 Percent, Due 2031
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.40%
TOTAL		$ 900	0
Debentures | Debenture 2021A, 2.40 Percent, Due 2031 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.40%
TOTAL		$ 900	0
Debentures | Debenture 2021A, 2.31 Percent, Due 2031
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.31%
TOTAL		$ 45	0
Debentures | Debenture Series 2003A, 5.875% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.875%
TOTAL		$ 175	175
Debentures | Debenture Series 2003A, 5.875% Due 2033 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.875%
TOTAL		$ 175	175
Debentures | Debenture Series 2003C, 5.10% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.10%
TOTAL		$ 200	200
Debentures | Debenture Series 2003C, 5.10% Due 2033 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.10%
TOTAL		$ 200	200
Debentures | Debenture Series 2004B, 5.70% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
Debentures | Debenture Series 2004B, 5.70% Due 2034 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
Debentures | Debenture Series 2005A, 5.30% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 350	350
Debentures | Debenture Series 2005A, 5.30% Due 2035 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 350	350
Debentures | Debenture Series 2005B, 5.25% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
Debentures | Debenture Series 2005B, 5.25% Due 2035 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
Debentures | Debenture Series 2006A, 5.85% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 400	400
Debentures | Debenture Series 2006A, 5.85% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 400	400
Debentures | Debenture Series 2006B, 6.20% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2006B, 6.20% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2006E, 5.70% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 250	250
Debentures | Debenture Series 2006E, 5.70% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 250	250
Debentures | Debenture Series 2007A, 6.30% Due 2037
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.30%
TOTAL		$ 525	525
Debentures | Debenture Series 2007A, 6.30% Due 2037 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.30%
TOTAL		$ 525	525
Debentures | Debenture 2008B, 6.75 Percent, Due 2038
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture 2008B, 6.75 Percent, Due 2038 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture 2009B, 6.00 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.00%
TOTAL		$ 60	60
Debentures | Debenture 2009C, 5.50 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture 2009C, 5.50 Percent, Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture 2019C, 3.46 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.46%
TOTAL		$ 38	38
Debentures | Debenture 2010B, 5.70 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture 2010B, 5.70 Percent, Due 2040 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture 2010B, 5.50 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 115	115
Debentures | Debenture 2012A, 4.20 Percent, Due 2042
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture 2012A, 4.20 Percent, Due 2042 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture 2013A, 3.95 Percent, Due 2043
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture 2013A, 3.95 Percent, Due 2043 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture 2014A, 4.45 Percent, Due 2044
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture 2014A, 4.45 Percent, Due 2044 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture 2015A, 4.50 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture 2015A, 4.50 Percent, Due 2045 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture 2015A, 4.95 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
TOTAL		$ 120	120
Debentures | Debenture Series 2015B, 4.69% due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.69%
TOTAL		$ 100	100
Debentures | Debenture 2016A, 3.85 Percent, Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	550
Debentures | Debenture 2016A, 3.85 Percent, Due 2046 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	550
Debentures | Debenture Series 2016A. 3.88% Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.88%
TOTAL		$ 75	75
Debentures | Debenture Series 2017A, 3.875% Due 2047
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.875%
TOTAL		$ 500	500
Debentures | Debenture Series 2017A, 3.875% Due 2047 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.875%
TOTAL		$ 500	500
Debentures | Debenture Series 2018E, 4.65% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.65%
TOTAL		$ 600	600
Debentures | Debenture Series 2018E, 4.65% Due 2048 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.65%
TOTAL		$ 600	600
Debentures | Debenture Series 2018A, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 125	125
Debentures | Debenture Series 2018B, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 25	25
Debentures | Debenture 2019A, 4.125 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.125%
TOTAL		$ 700	700
Debentures | Debenture 2019A, 4.125 Percent, Due 2049 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.125%
TOTAL		$ 700	700
Debentures | Debenture 2019A, 3.73 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.73%
TOTAL		$ 43	43
Debentures | Debenture 2020B, 3.95 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	1,000
Debentures | Debenture 2020B, 3.95 Percent, Due 2050 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	1,000
Debentures | Debenture 2020B, 3.24 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.24%
TOTAL		$ 40	40
Debentures | Debenture 2021B, 3.170 Percent, Due 2051
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.17%
TOTAL		$ 30	0
Debentures | Debenture 2021C, 3.20 Percent, Due 2051
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.20%
TOTAL		$ 600	0
Debentures | Debenture 2021C, 3.200 Percent, Due 2051 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.20%
TOTAL		$ 600	0
Debentures | Debenture Series 2014C, 4.625% Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures | Debenture Series 2014C, 4.625% Due 2054 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures | Debenture Series 2016C, 4.30% Due 2056
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	500
Debentures | Debenture Series 2016C, 4.30% Due 2056 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	500
Debentures | Debenture Series 2017C, 4.00% Due 2057
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 350	350
Debentures | Debenture Series 2017C, 4.00% Due 2057 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 350	350
Debentures | Debenture Series 2018B, 4.50% Due 2058
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 700	700
Debentures | Debenture Series 2018B, 4.50% Due 2058 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 700	700
Debentures | Debenture 2019B, 3.70 Percent, Due 2059
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.70%
TOTAL		$ 600	600
Debentures | Debenture 2019B, 3.70 Percent, Due 2059 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.70%
TOTAL		$ 600	600
Debentures | Debenture 2018C, 2.75 Percent, Due 2021 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.60%
TOTAL		$ 0	640
Debentures | Debenture 2020C, 3.00 Percent, Due 2060
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.00%
TOTAL		$ 600	600
Debentures | Debenture 2020C, 3.00 Percent, Due 2060 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.00%
TOTAL		$ 600	600
Debentures | Debenture 2021B, 3.60 Percent, Due 2061
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.60%
TOTAL		$ 750	0
Debentures | Debenture 2021B, 3.60 Percent, Due 2061 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.60%
TOTAL		$ 750	0
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		450	450
Tax-Exempt Debt | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 450	450
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	0.10%
TOTAL PROJECT DEBT	[2]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	0.10%
TOTAL	[3]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	0.10%
TOTAL PROJECT DEBT	[2]	$ 99	99
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	0.10%
TOTAL	[3]	$ 99	99
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[2]	0.09%
TOTAL PROJECT DEBT	[2]	$ 126	126
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[3]	0.09%
TOTAL	[3]	$ 126	$ 126
[1]	(b) December 31, 2021 effective rates shown, reflecting variable interest rates on the debt that are reset quarterly or semi-annually and the effect of applicable interest rate swaps, if any.
[2]	Rates reset weekly; December 31, 2021 rates shown.
[3]	Rates reset weekly; December 31, 2021 rates shown.

General

General	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R. As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.

Summary of Significant Accounti

Summary of Significant Accounting Policies and Other Matters	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Summary of Significant Accounting Policies and Other Matters	Summary of Significant Accounting Policies and Other Matters Principles of Consolidation The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note S), as required. All intercompany balances and intercompany transactions have been eliminated. Accounting Policies The accounting policies of Con Edison and its subsidiaries conform to generally accepted accounting principles in the United States of America (GAAP). For the Utilities, these accounting principles include the accounting rules for regulated operations and the accounting requirements of the Federal Energy Regulatory Commission (FERC) and the state regulators having jurisdiction. The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations. The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2021 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators. Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow. Revenues CECONY’s electric and gas rate plans and O&R’s NY electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B. The NYSPSC requires utilities to record gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expense). The recovery of these taxes is generally provided for in the revenue requirement within each of the respective NYSPSC-approved rate plans. Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $358 $335 $323 CECONY 346 323 312 For information about the Companies' revenue recognition policies, see Note M. Plant and Depreciation Utility Plant Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (AFUDC). The original cost of property is charged to expense over the estimated useful lives of the assets. Upon retirement, the original cost of property is charged to accumulated depreciation. See Note T. Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 4.5 percent, 5.2 percent and 5.1 percent for 2021, 2020 and 2019, respectively. The AFUDC rates for O&R were 4.8 percent, 5.3 percent and 5.3 percent for 2021, 2020 and 2019, respectively. The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.5 percent for 2021 and 3.5 percent for 2020 and 3.2 percent for 2019. The average depreciation rates for O&R were 3.1 percent for 2021, 3.2 percent for 2020 and 3.0 percent for 2019. The estimated lives for utility plant for CECONY range from 5 to 85 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant. At December 31, 2021 and 2020, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Electric Generation $559 $572 $559 $572 Transmission 3,955 3,786 3,658 3,496 Distribution 22,418 21,481 21,240 20,366 General 87 52 87 52 Gas (a) 10,473 9,206 9,748 8,522 Steam 1,924 1,854 1,924 1,854 General 2,566 2,507 2,338 2,286 Held for future use 80 92 72 84 Construction work in progress 2,152 2,474 1,985 2,320 Net Utility Plant $44,214 $42,024 $41,611 $39,552 (a) Primarily distribution. General utility plant of Con Edison and CECONY included $79 million and $74 million, respectively, at December 31, 2021, and $86 million and $81 million, respectively, at December 31, 2020, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense related to the software licenses for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $24 million at December 31, 2021 and $17 million at December 31, 2020. Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2021 was $1,802 million, including $1,710 million under CECONY’s electric, gas and steam rate plans that have been approved by the NYSPSC. Non–Utility Plant Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on non-utility plant, other than land, is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years. Other Deferred Charges and Noncurrent Assets and Prepayments Other deferred charges and noncurrent assets and prepayments, net of accumulated depreciation, included the following related to implementation costs incurred in cloud computing arrangements: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Prepayments (a)(b) $16 $12 $15 $11 Other Deferred Charges and Noncurrent Assets (a)(b) $81 $54 $78 $51 (a) Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Depreciation expense related to these assets incurred during the year ended December 31, 2021 for Con Edison and CECONY was $12 million and $11 million, respectively, and for the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $22 million and $19 million, respectively at December 31, 2021 and was $10 million and $8 million, respectively at December 31, 2020. Long–Lived and Intangible Assets The Companies test long-lived and intangible assets for recoverability when events or changes in circumstances indicate that the carrying value of long-lived or intangible assets may not be recoverable. The carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value. Con Edison's intangible assets with definite lives consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by the Clean Energy Businesses in 2016 and 2018. At December 31, 2021 and 2020, intangible assets arising from power purchase agreements were $1,290 million and $1,457 million, net of accumulated amortization of $288 million and $220 million, respectively, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $3 million, net of accumulated amortization of $9 million and $8 million, at December 31, 2021 and 2020, respectively. CECONY’s other intangible assets were immaterial at December 31, 2021 and 2020. Con Edison recorded amortization expense related to its intangible assets of $95 million in 2021, $102 million in 2020, and $99 million in 2019. Con Edison expects amortization expense to be $95 million per year over the next five years. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2021 or 2020. Recoverable Energy Costs The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month, the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs and costs of its electric demand management programs are generally deferred for charge or refund to customers during the next billing cycle (normally within one New York Independent System Operator (NYISO) The Utilities purchase electricity through the wholesale electricity market administered by the NYISO. The difference between purchased power and related costs initially billed to the Utilities by the NYISO and the actual cost of power subsequently calculated by the NYISO is refunded by the NYISO to the Utilities, or paid to the NYISO by the Utilities. The reconciliation payments or receipts are recoverable from or refundable to the Utilities’ customers. Certain other payments to or receipts from the NYISO are also subject to reconciliation, with shortfalls or amounts in excess of specified rate allowances recoverable from or refundable to customers. These include proceeds from the sale through the NYISO of transmission rights on CECONY’s transmission system (transmission congestion contracts or TCCs). Temporary Cash Investments Temporary cash investments are short-term, highly-liquid investments that generally have maturities of three months or less at the date of purchase. They are stated at cost, which approximates market. The Companies consider temporary cash investments to be cash equivalents. Investments Accounting for Investments Con Edison’s investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities’ supplemental retirement income plan and deferred income plan assets. The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a market valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any. The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above. Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach) In 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET Gas) and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million, including closing adjustments, was attributed to CET Gas for its 50 percent interest. The purchase and sale agreement provided for a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the year ended December 31, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest in Stagecoach of $212 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the year ended December 31, 2021. Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 reflected the final sales price received in July 2021 and the remaining amount received in November 2021, including closing adjustments. 2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed 300-mile gas transmission project (the Project) in West Virginia and Virginia. During 2019, Con Edison exercised its right to limit, and did limit, its cash contributions to the joint venture to approximately $530 million, which reduced CET Gas' interest in MVP to 11.3 percent and 10.2 percent as of December 31, 2020 and 2021, respectively. CET Gas' interest in MVP is expected to be reduced to 8.5 percent based on the Project's current cost estimate and CET Gas' previous capping of its cash contributions. As of December 31, 2020 and 2021, the Project was approximately 92 percent and 94 percent complete, respectively. During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in a portion of the Project in West Virginia, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this certificate amendment would have led to additional Project costs and would have extended the anticipated in-service date. In January 2021, the FERC did not approve the requested certificate amendment. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a new certificate amendment application to the FERC to bore under other water crossings that, in total, would cover the entire Project length. The uncertainty related to obtaining necessary water crossing permits, the resulting Project costs and the likelihood of the Project not reaching eventual completion increased as a result of actions taken by the U.S. Court of Appeals for the Fourth Circuit. This action and associated delays constituted a triggering event (the "2020 triggering event") that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. In December 2021, the Virginia Department of Environmental Quality and the West Virginia Department of Environmental Protection both issued water quality certification permits which are required in order for the U.S. Army Corps of Engineers to proceed with the permitting process for construction of certain Project water crossings. In January 2022, the U.S. Court of Appeals for the Fourth Circuit rejected permits for crossings through the Jefferson National Forest issued by the U.S. Forest Service and Bureau of Land Management. In February 2022, the U.S. Court of Appeals for the Fourth Circuit vacated a biological opinion from the U.S. Fish and Wildlife Service, applicable to all remaining construction. The biological opinion had been issued and was the subject of litigation prior to December 31, 2021. Con Edison believes that the February 2022 action by the U.S. Court of Appeals for the Fourth Circuit, along with the potential outcome of other matters pending before that Court, may lead to further delays and increased Project costs, which constituted a triggering event (the “2021 triggering event”) that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2021. In response to the 2020 triggering event and 2021 triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis as of December 31, 2020 and 2021, respectively. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note U. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. For the 2020 triggering event, Con Edison estimated that the likelihood of Project completion was in the upper end of a reasonably possible range. For the 2021 triggering event, Con Edison anticipated that the Project faces legal and regulatory challenges that make construction completion increasingly remote. The Project faces additional delays and increased costs that could further reduce CET Gas' interest in MVP to below 8 percent based on CET Gas' previous capping of its cash contributions. The likelihood that the Project will be completed and, for 2020, the discount rate, are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation. Based on the discounted cash flow analyses, Con Edison concluded as of December 31, 2020 and 2021 that the fair value of its investment in MVP declined below its carrying value and the declines were other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million, with an associated deferred tax asset of $53 million. Additionally, Con Edison recorded a pre-tax impairment loss of $231 million ($162 million, after tax) for the year ended December 31, 2021 that reduced the carrying value of its investment in MVP from $342 million to $111 million, with an additional $77 million associated deferred tax asset, totaling a deferred tax asset of $130 million at December 31, 2021. The impairments were recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison did not record non-cash equity in earnings from allowance for funds used during construction from MVP beginning in January 2021 and will continue to refrain from recording such amounts until such time as substantial construction activities resume, which would be indicative of probable Project completion. There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP. Summary of Investment Balances The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2021 and 2020: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 CET Gas investment in Stagecoach Gas Services LLC $— $845 $— $— CET Gas investment in Mountain Valley Pipeline, LLC (a) 111 342 — — Supplemental retirement income plan assets (b) 525 465 499 439 Deferred income plan assets 102 92 102 92 CET Electric investment in New York Transco, LLC (c) 112 69 — — Other 3 3 7 10 Total investments $853 $1,816 $608 $541 (a) At December 31, 2021 and 2020, CET Gas' cash investment in MVP was $530 million. In May 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is targeting an in-service date for the project of summer 2022 at an overall project cost of approximately $6,200 million excluding allowance for funds used during construction. See "2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E. (c) CET Electric owns a 45.7 percent interest in New York Transco, LLC. Pension and Other Postretirement Benefits The accounting rules for retirement benefits require an employer to recognize an asset or liability for the overfunded or underfunded status of its pension and other postretirement benefit plans. For a pension plan, the asset or liability is the difference between the fair value of the plan’s assets and the projected benefit obligation. For any other postretirement benefit plan, the asset or liability is the difference between the fair value of the plan’s assets and the accumulated postretirement benefit obligation. The accounting rules generally require employers to recognize all unrecognized prior service costs and credits and unrecognized actuarial gains and losses in accumulated other comprehensive income/(loss) (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of total periodic benefit cost or income pursuant to the current recognition and amortization provisions. For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. Unrecognized prior service costs or credits and unrecognized actuarial gains and losses are recorded to regulatory assets or liabilities, rather than OCI. See Notes E and F. The total periodic benefit costs are recognized in accordance with the accounting rules for retirement benefits. Investment gains and losses are recognized in expense over a 15-year period and other actuarial gains and losses are recognized in expense over a 10-year period, subject to the deferral provisions in the rate plans. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between such expenses and the amounts for such expenses reflected in rates. O&R also defers such difference pursuant to its NY rate plans. See Note B. The Companies calculate the expected return on pension and other postretirement benefit plan assets by multiplying the expected rate of return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. The accounting rules allow the MRV of plan assets to be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. The Companies use a calculated value when determining the MRV of the plan assets that adjusts for 20 percent of the difference between fair value and expected MRV of plan assets. This calculated value has the effect of stabilizing variability in assets to which the Companies apply the expected return. Federal Income Tax In accordance with accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability at current tax rates for temporary differences between the book and tax basis of assets and liabilities. In accordance with rate plans, the Utilities have recovered amounts from customers for a portion of the tax liability they will pay in the future as a result of the reversal or “turn-around” of these temporary differences. As to the remaining deferred tax liability, the Utilities had established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense pursuant to the NYSPSC's 1993 Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense. Con Edison and its subsidiaries file a consolidated federal income tax return. The consolidated income tax liability is allocated to each member of the consolidated group using the separate return method. Each member pays or receives an amount based on its own taxable income or loss in accordance with a consolidated tax allocation agreement. Tax loss and tax credit carryforwards are allocated among members in accordance with consolidated tax return regulations. State Income Tax Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member’s share of the New York State tax is based on its own New York State taxable income or loss. Research and Development Costs Research and development costs are charged to operating expenses as incurred. Research and development costs were as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $25 $24 $24 CECONY 24 23 23 Reclassification Certain prior year amounts have been reclassified to conform with current year presentation. Earnings Per Common Share Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the exercise price (see Note O) and its common shares that are subject to forward sale agreements (see Note C). Before the issuance of common shares upon settlement of the forward sale agreements, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period). Basic and diluted EPS for Con Edison are calculated as follows: For the Years Ended December 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2021 2020 2019 Net income for common stock $1,346 $1,101 $1,343 Weighted average common shares outstanding – basic 348.4 334.8 328.5 Add: Incremental shares attributable to effect of potentially dilutive securities 1.0 0.9 1.0 Adjusted weighted average common shares outstanding – diluted 349.4 335.7 329.5 Net Income per common share – basic $3.86 $3.29 $4.09 Net Income per common share – diluted $3.85 $3.28 $4.08 The computation of diluted EPS for the years ended December 31, 2021, 2020 and 2019 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect. Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Changes in Accumulated Other Comprehensive Income/(Loss) by Component Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: (Millions of Dollars) Con Edison CECONY Accumulated OCI, net of taxes, at December 31, 2018 (a) $(16) $(5) OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respect

Regulatory Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Regulatory Matters	Note B – Regulatory Matters Rate Plans The Utilities provide service to NY customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s NJ regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that the Utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ NY rate plans include: Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers. Cost reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds. Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable. Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity. Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters. Other revenue adjustments represent positive revenue adjustments, positive incentives, and earnings adjustments mechanisms for achievement of performance standards related to achievement of clean energy goals, safety and other matters. Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates. Rate base , as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre – tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020 and 2021, the company recorded $34 million and $64 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020 and 2021, the company deferred for recovery from customers $242 million and $226 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020 and $3.2 million as a regulatory liability in 2021. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) (j) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Yr. 2 – 8.03 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (e) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points. (f) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. In January 2022, CECONY filed a request with the NYSPSC for an electric rate increase of $1,199 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $853 million and $608 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020 and 2021, the company recorded $3 million and $26 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020 and 2021, the company recorded positive incentives of $13 million and $7 million, respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020 and 2021, the company deferred for recovery from customers $27 million and $100 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020 and 2021, the company deferred $24.7 million and $26 million as a regulatory liability, respectively. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.8 percent Actual return on common equity (i) (j) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Yr. 2 – 8.48 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. In January 2022, CECONY filed a request with the NYSPSC for a gas rate increase of $503 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filed gas revenue requirement includes additional depreciation expense of $48 million. Included in this increase is the impact of the company’s proposal to decrease the service lives for the longer-lived gas accounts by five years. The filing includes supplemental information regarding gas rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $234 million and $218 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2021, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020 and 2021, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets and $32 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020 and by $0.6 million in 2021. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020 and 2021, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. In October 2021, O&R, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for new electric and gas rate plans for the three-year period January 2022 through December 2024 (the Joint Proposal). The Joint Proposal is subject to NYSPSC approval. The Joint Proposal includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ( $2.8 million ); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. The following tables contain a summary of the current and proposed rate plans. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $1

Capitalization

Capitalization	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Capitalization	Capitalization Common Stock Con Edison is authorized to issue 500,000,000 shares of its common stock and CECONY is authorized to issue 340,000,000 of its common stock. At December 31, 2021 and 2020, 353,983,712 and 342,297,534 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2021 and 2020, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2021 and 2020, Con Edison had 23,210,700 treasury shares, including 21,976,200 shares of Con Edison stock that CECONY purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity. In June 2021, Con Edison issued 10,100,000 shares of its common stock resulting in net proceeds of approximately $775 million, after issuance expenses. Capitalization of Con Edison Con Edison's capitalization shown on its Consolidated Statement of Capitalization includes its outstanding common stock and long-term debt and the outstanding long-term debt of the Utilities and the Clean Energy Businesses. Dividends In accordance with NYSPSC requirements, the dividends that the Utilities generally pay are limited to not more than 100 percent of their respective income available for dividends calculated on a two–year rolling average basis. See Note U. Excluded from the calculation of “income available for dividends” are non-cash charges to income resulting from accounting changes or charges to income resulting from significant unanticipated events. The restriction also does not apply to dividends paid in order to transfer to Con Edison proceeds from major transactions, such as asset sales, or to dividends reducing each utility subsidiary’s equity ratio to a level appropriate to its business risk. Long-term Debt Long-term debt maturing in the period 2022-2026 is as follows: (Millions of Dollars) Con Edison CECONY 2022 $440 $— 2023 969 — 2024 393 250 2025 319 — 2026 385 250 CECONY has issued $450 million of tax – exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bears interest at a rate determined weekly and is subject to tender by bondholders for purchase by the company. The carrying amounts and fair values of long-term debt at December 31, 2021 and 2020 are: (Millions of Dollars) 2021 2020 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $23,044 $26,287 $22,349 $26,808 CECONY $18,382 $21,382 $16,789 $20,974 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $226 million and $193 million for Con Edison and CECONY, respectively, as of December 31, 2021 and $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020. The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2021 are classified as Level 2 (see Note R). Significant Debt Covenants The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other entity unless certain conditions are met. In addition, Con Edison’s notes include covenants that the company shall continue its utility business in New York City and shall not permit its ratio of consolidated debt to consolidated total capital to exceed 0.675 to 1 and include cross default provisions with respect to the failure by the company or any material subsidiary to make one or more payments in respect of material financial obligations (in excess of an aggregate $100 million of debt, excluding non-recourse debt, of the company or any of its material subsidiaries and the occurrence of an event or condition which results in the acceleration of the maturity of any material debt in excess of an aggregate $100 million, not including non-recourse debt, of the company or any of its material subsidiaries or enables the holders of such debt to accelerate the maturity thereof. The Companies' debentures have no cross default provisions. The tax–exempt financing arrangements of CECONY are subject to covenants for the debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2021. The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of CECONY to NYSERDA in exchange for the net proceeds of a like amount of tax – exempt bonds with substantially the same terms sold to the public by NYSERDA. The tax-exempt financing arrangements include covenants with respect to the tax – exempt status of the financing, including covenants with respect to the use of the facilities financed. The arrangements include provisions for the maintenance of liquidity and credit facilities, the failure to comply with which would, except as otherwise provided, constitute an event of default for the debt to which such provisions applied. The failure to comply with debt covenants would, except as otherwise provided, constitute an event of default for the debt to which such provisions applied. If an event of default were to occur, the principal and accrued interest on the debt to which such event of default applied and, in the case of the Con Edison notes, a make-whole premium might and, in the case of certain events of default would, become due and payable immediately. The liquidity and credit facilities currently in effect for the tax – exempt financing include covenants that the ratio of debt to total capital of CECONY will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, CECONY will not mortgage, lien, pledge or otherwise encumber its assets. Certain of the facilities also include as events of default, defaults in payments of other debt obligations in excess of specified levels ($150 million or $100 million, depending on the facility).

Short-Term Borrowing

Short-Term Borrowing	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Short-Term Borrowing	Short-Term Borrowing In December 2016, Con Edison and the Utilities entered into a credit agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. The Credit Agreement, as amended in 2019, expires in December 2023. There is a maximum of $2,250 million of credit available through December 2022 and $2,200 million of credit available from then through December 2023 . The full amount is available to CECONY and $1,000 million (subject to increase up to $1,500 million) is available to Con Edison, including up to $1,200 million of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. At December 31, 2021, Con Edison had $1,488 million of commercial paper outstanding, of which $1,361 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2021 was 0.3 percent for both Con Edison and CECONY. At December 31, 2020, Con Edison had $1,705 million of commercial paper outstanding of which $1,660 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2020 was 0.3 percent for both Con Edison and CECONY. At December 31, 2021 and 2020, no loans were outstanding under the Credit Agreement. An immaterial amount of letters of credit were outstanding under the Credit Agreement as of December 31, 2021 and 2020. The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default for a company include that company exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2021 this ratio was 0.52 to 1 for Con Edison and 0.55 to 1 for CECONY); that company having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; that company or any of its material subsidiaries failing to make one or more payments in respect of material financial obligations (in excess of an aggregate $150 million of debt or derivative obligations other than non-recourse debt) of that company; the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $150 million of debt other than non-recourse debt) of that company or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their significant debt covenants at December 31, 2021. See Note U for information about short-term borrowing between related parties.

Pension Benefits

Pension Benefits	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Pension Benefits	Pension Benefits Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY, O&R and Con Edison Transmission and certain employees of the Clean Energy Businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. Con Edison also maintains additional non – qualified supplemental pension plans. Total Periodic Benefit Cost The components of the Companies’ total periodic benefit costs for 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost – including administrative expenses $343 $293 $250 $321 $274 $232 Interest cost on projected benefit obligation 471 549 601 443 515 564 Expected return on plan assets (1,096) (1,034) (988) (1,040) (980) (936) Recognition of net actuarial loss 787 699 518 746 661 492 Recognition of prior service credit (17) (16) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $488 $491 $364 $451 $451 $333 Cost capitalized (154) (130) (108) (146) (123) (102) Reconciliation to rate level (226) (250) (15) (216) (239) (12) Total expense recognized $108 $111 $241 $89 $89 $219 In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The Companies adopted ASU 2017-07 beginning on January 1, 2018. The guidance requires that components of net periodic benefit cost other than service cost be presented outside of operating income on consolidated income statements, and that only the service cost component is eligible for capitalization. Accordingly, the service cost components are included in the line "Other operations and maintenance" and the non-service cost components are included in the line “Other deductions” in the Companies' consolidated income statements. In August 2018, the FASB issued amendments to the guidance for retirement benefits through ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The guidance requires disclosure of the weighted-average interest crediting rate used for cash balance plans for all periods presented, and a narrative description of significant changes in the benefit obligation. The Companies adopted ASU 2018-14 for fiscal years ending after December 15, 2020 and the required disclosures are included below and, as applicable, in Note F. Funded Status The funded status at December 31, 2021, 2020 and 2019 was as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 Service cost – excluding administrative expenses 337 288 245 317 269 228 Interest cost on projected benefit obligation 471 549 601 443 515 564 Net actuarial loss/(gain) (1,547) 2,281 2,191 (1,441) 2,154 2,076 Plan amendments — — 15 — — — Benefits paid (869) (945) (709) (799) (867) (660) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 Actual return on plan assets 1,935 1,927 2,556 1,838 1,830 2,425 Employer contributions 469 475 350 432 435 318 Benefits paid (869) (945) (709) (799) (867) (660) Administrative expenses (53) (43) (39) (52) (41) (37) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 FUNDED STATUS $1,147 $(1,943) $(1,184) $1,225 $(1,674) $(960) Unrecognized net loss $205 $3,330 $2,604 $207 $3,145 $2,466 Unrecognized prior service costs/(credits) (140) (156) (173) (163) (183) (202) Accumulated benefit obligation 15,469 16,768 15,015 14,504 15,676 14,010 The increase in the pension funded status at December 31, 2021 for Con Edison and CECONY of $3,090 million and $2,899 million, respectively, compared with December 31, 2020, was primarily due to a decrease in the plan's projected benefit obligation as a result of an increase in the discount rate and actuarial gains on plan assets exceeding the expected rate of return. The increase in the pension funded status liability at December 31, 2020 for Con Edison and CECONY of $759 million and $714 million, respectively, compared with December 31, 2019, was primarily due to an increase in the plan’s projected benefit obligation as a result of a decrease in the discount rate, partially offset by an increase in plan assets as a result of the actual return on plan assets. See below for further information on the change in the discount rate and determination of the discount rate assumption. For Con Edison, the 2021 change in pension funded status from a liability to an asset corresponds with a decrease to regulatory assets of $3,067 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $30 million (net of taxes) for the unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses, Con Edison Transmission, and RECO who previously worked for the Utilities. For 2021, included within the funded status are noncurrent liabilities of $459 million and $381 million for Con Edison and CECONY, respectively. For CECONY, the change in pension funded status from a liability to an asset at December 31, 2021 corresponds with a decrease to regulatory assets of $2,910 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, and also a credit to OCI of $6 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY. At December 31, 2021 and 2020, Con Edison’s investments included $525 million and $465 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $499 million and $439 million, respectively. See Note R. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $386 million and $352 million as of December 31, 2021, respectively, and $414 million and $377 million as of December 31, 2020, respectively. Assumptions The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Expected return on plan assets 7.00 % 7.00 % 7.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % The expected return assumption reflects anticipated returns on the plan’s current and future assets. The Companies’ expected return was based on an evaluation of the current environment, market and economic outlook, relationships between the economy and asset class performance patterns, and recent and long-term trends in asset class performance. The projections were based on the plan’s target asset allocation. Discount Rate Assumption To determine the assumed discount rate, the Companies use a model that produces a yield curve based on discounting plan specific cash flows with corresponding spot rates on a yield curve. Term structures of interest rates are based on AA rated corporate bonds. Bonds with questionable pricing information and bonds that are not representative of the overall market are excluded from consideration. For example, the bonds used in the model cannot be callable (with the exception of "make whole" callable bonds). The spot rates defined by the yield curve and the plan’s projected benefit payments are used to develop a weighted average discount rate. Expected Benefit Payments Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $765 $782 $791 $841 $818 $4,219 CECONY 704 721 730 780 756 3,924 Expected Contributions Based on estimates as of December 31, 2021, the Companies expect to make contributions to the pension plans during 2022 of $29 million (of which $20 million is to be made by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. Plan Assets The asset allocations for the pension plan at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 45% - 55% 50 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 38 % Real Estate 10% - 14% 12 % 11 % 11 % Total 100% 100 % 100 % 100 % Con Edison has established a pension trust for the investment of assets to be used for the exclusive purpose of providing retirement benefits to participants and beneficiaries and payment of plan expenses. Pursuant to resolutions adopted by Con Edison’s Board of Directors, the Management Development and Compensation Committee of the Board of Directors (the Committee) has general oversight responsibility for Con Edison’s pension and other employee benefit plans. The pension plan’s named fiduciaries have been granted the authority to control and manage the operation and administration of the plans, including overall responsibility for the investment of assets in the trust and the power to appoint and terminate investment managers. The investment objectives of the Con Edison pension plan are to maintain a level and form of assets adequate to meet benefit obligations to participants, to achieve the expected long-term total return on the trust assets within a prudent level of risk and maintain a level of volatility that is not expected to have a material impact on the company’s expected contribution and expense or the company’s ability to meet plan obligations. The assets of the plan have no significant concentration of risk in one country (other than the United States), industry or entity. The strategic asset allocation is intended to meet the objectives of the pension plan by diversifying its funds across asset classes, investment styles and fund managers. An asset/liability study typically is conducted every few years to determine whether the current strategic asset allocation continues to represent the appropriate balance of expected risk and reward for the plan to meet expected liabilities. Each study considers the investment risk of the asset allocation and determines the optimal asset allocation for the plan. The target asset allocation for 2022 reflects the results of such a study conducted in 2018. Individual fund managers operate under written guidelines provided by Con Edison, which cover such areas as investment objectives, performance measurement, permissible investments, investment restrictions, trading and execution, and communication and reporting requirements. Con Edison management regularly monitors, and the named fiduciaries review and report to the Committee regarding, asset class performance, total fund performance, and compliance with asset allocation guidelines. Management changes fund managers and rebalances the portfolio as appropriate. At the direction of the named fiduciaries, such changes are reported to the Committee. Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note R). The fair values of the pension plan assets at December 31, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists of global equity funds that are not exchange-traded. (j) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (k) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (l) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F. (m) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end. (n) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2021 by asset category. The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $55 $52 $49 CECONY 46 43 42

Other Postretirement Benefits

Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Other Postretirement Benefits	Other Postretirement Benefits The Utilities and Con Edison Transmission currently have contributory comprehensive hospital, medical and prescription drug programs for eligible retirees, their dependents and surviving spouses. CECONY also has a contributory life insurance program for bargaining unit employees and provides basic life insurance benefits up to a specified maximum at no cost to certain retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of the Clean Energy Businesses and Con Edison Transmission are eligible to receive benefits under these programs. Total Periodic Benefit Cost The components of the Companies’ total periodic postretirement benefit costs for 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost $22 $21 $18 $16 $16 $13 Interest cost on accumulated other postretirement benefit obligation 33 37 44 28 31 36 Expected return on plan assets (68) (66) (66) (56) (54) (54) Recognition of net actuarial loss/(gain) 31 37 (9) 27 36 (10) Recognition of prior service credit (3) (3) (2) (1) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $15 $26 $(15) $14 $27 $(17) Cost capitalized (9) (9) (7) (7) (7) (5) Reconciliation to rate level (7) (17) 12 (12) (25) 7 Total credit recognized $(1) $— $(10) $(5) $(5) $(15) For information about the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans," see Note E. Funded Status The funded status of the programs at December 31, 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,425 $1,357 $1,114 $1,209 $1,154 $913 Service cost 22 21 18 16 16 13 Interest cost on accumulated postretirement benefit obligation 33 37 44 28 31 36 Amendments — — (14) — — — Net actuarial loss/(gain) (13) 74 264 (3) 63 252 Benefits paid and administrative expenses, net of subsidies (117) (117) (110) (107) (107) (100) Participant contributions 48 53 41 46 52 40 BENEFIT OBLIGATION AT END OF YEAR $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,115 $1,026 $885 $940 $872 $759 Actual return on plan assets 92 142 198 67 117 165 Employer contributions 6 7 7 3 4 6 Employer group waiver plan subsidies 21 20 23 19 19 22 Participant contributions 48 53 40 46 51 40 Benefits paid (132) (133) (127) (120) (123) (120) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,150 $1,115 $1,026 $955 $940 $872 FUNDED STATUS $(248) $(310) $(331) $(234) $(269) $(282) Unrecognized net loss/(gain) $41 $115 $155 $67 $114 $149 Unrecognized prior service costs (13) (16) (19) — (1) (3) The decrease in the other postretirement benefits funded status liability at December 31, 2021 for Con Edison and CECONY of $62 million and $35 million, respectively, compared with December 31, 2020, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, along with a decrease in the plans' projected benefit obligation as a result of an increase in the discount rate. See below for further information on the change in the discount rate and see Note E for determination of the discount rate assumption. The decrease in the other postretirement benefits funded status liability at December 31, 2020 for Con Edison and CECONY of $21 million and $13 million, respectively, compared with December 31, 2019, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, partially offset by an increase in the plans' projected benefit obligation as a result of a decrease in the discount rate. For 2021, included within the funded status are noncurrent assets of $79 million and $55 million for Con Edison and CECONY, respectively. For Con Edison, the decrease in funded status liability at December 31, 2021 corresponds with a net decrease to regulatory assets of $67 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and immaterial changes to OCI for the unrecognized net losses and the unrecognized prior service costs associated with the Clean Energy Businesses, Con Edison Transmission, and RECO. For CECONY, the decrease in funded status liability at December 31, 2021 corresponds with a decrease to regulatory assets of $46 million for unrecognized net losses and the unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and immaterial changes to OCI for the unrecognized net losses and the unrecognized prior service costs associated with eligible employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY. Assumptions The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Expected Return on Plan Assets 6.80 % 6.80 % 6.80 % Refer to Note E for descriptions of the basis for determining the expected return on assets, investment policies and strategies and the assumed discount rate. The health care cost trend rates for covered medical and prescription medication expenses used to determine the accumulated other postretirement benefit obligations (APBO) at December 31, 2021 were assumed to increase each year, with the initial rate gradually decreasing to the ultimate rate as follows: Initial Cost Trend Rate Ultimate Cost Trend Rate Year That Ultimate Rate is Reached Pre-65 Medical 6.80% 4.50% 2034 Post-65 Medical 4.50% 4.50% — Prescription Medications 7.25% 4.50% 2033 Expected Benefit Payments Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies and participant contributions: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $75 $77 $77 $78 $78 $385 CECONY 84 86 86 87 88 435 Expected Contributions Based on estimates as of December 31, 2021, Con Edison and CECONY expect to make a contribution of $8 million (all of which is expected to be made by CECONY) to the other postretirement benefit plans in 2022. The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible. Plan Assets The asset allocations for CECONY’s other postretirement benefit plans at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 42%-80% 55 % 54 % 54 % Debt Securities 20%-58% 45 % 46 % 46 % Total 100% 100 % 100 % 100 % Con Edison has established postretirement health and life insurance benefit plan trusts for the investment of assets to be used for the exclusive purpose of providing other postretirement benefits to participants and beneficiaries. Refer to Note E for a discussion of Con Edison’s investment policy for its benefit plans. The fair values of the plans' assets at December 31, 2021 by asset category as defined by the accounting rules for fair value measurements (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note E. (e) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. (f) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year-end. The fair values of the plans' assets at December 31, 2020 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115

Environmental Matters

Environmental Matters	12 Months Ended
	Dec. 31, 2021
Environmental Remediation Obligations [Abstract]
Environmental Matters	Environmental Matters Superfund Sites Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored. The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.” For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites. The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Accrued Liabilities: Manufactured gas plant sites $845 $752 $755 $676 Other Superfund Sites 95 105 95 104 Total $940 $857 $850 $780 Regulatory assets $938 $865 $860 $791 Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) prudently incurred site investigation and remediation costs. Environmental remediation costs incurred related to Superfund Sites at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Remediation costs incurred $25 $33 $24 $32 Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2021 and 2020. Con Edison and CECONY estimate that in 2022 they will incur costs for remediation of approximately $40 million and $38 million, respectively. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. In 2021, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2,980 million and $2,840 million, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different. Asbestos Proceedings Suits have been brought in NY State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At December 31, 2021, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims. The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets or liabilities for the Companies at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $65 $72 $62 $68 Regulatory liabilities – workers’ compensation $8 $3 $8 $3

Material Contingencies

Material Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Material Contingencies	10 years Total (Millions of Dollars) Con Edison Transmission $490 $— $— $490 Energy transactions 469 37 325 831 Renewable electric projects 319 51 396 766 Other 70 — — 70 Total $1,348 $88 $721 $2,157 Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET Electric’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Projects – Con Edison and the Clean Energy Businesses guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities." id="sjs-B4">Material Contingencies Manhattan Explosion and Fire On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Streets in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC. In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. In February 2017, the NYSPSC approved a settlement agreement with the company related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, the company is providing $27 million of future benefits to customers (for which it has accrued a regulatory liability) and will not recover from customers $126 million of costs for gas emergency response activities that it had previously incurred and expensed. Approximately eighty suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. During 2020, the company accrued its estimated liability for the suits of $40 million and an insurance receivable in the same amount, which estimated liability did not change in 2021. Other Contingencies For additional contingencies, see “Other Regulatory Matters” in Note B, Note G and "Uncertain Tax Positions" in Note L. Guarantees Con Edison and its subsidiaries have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison and its subsidiaries under these agreements totaled $2,157 million and $2,042 million at December 31, 2021 and 2020, respectively. A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2021 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $490 $— $— $490 Energy transactions 469 37 325 831 Renewable electric projects 319 51 396 766 Other 70 — — 70 Total $1,348 $88 $721 $2,157 Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET Electric’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Projects – Con Edison and the Clean Energy Businesses guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities.

Electricity Purchase Agreements

Electricity Purchase Agreements	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Electricity Purchase Agreements	Note B – Regulatory Matters Rate Plans The Utilities provide service to NY customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s NJ regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that the Utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ NY rate plans include: Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers. Cost reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds. Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable. Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity. Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters. Other revenue adjustments represent positive revenue adjustments, positive incentives, and earnings adjustments mechanisms for achievement of performance standards related to achievement of clean energy goals, safety and other matters. Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates. Rate base , as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre – tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020 and 2021, the company recorded $34 million and $64 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020 and 2021, the company deferred for recovery from customers $242 million and $226 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020 and $3.2 million as a regulatory liability in 2021. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) (j) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Yr. 2 – 8.03 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (e) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points. (f) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. In January 2022, CECONY filed a request with the NYSPSC for an electric rate increase of $1,199 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $853 million and $608 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020 and 2021, the company recorded $3 million and $26 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020 and 2021, the company recorded positive incentives of $13 million and $7 million, respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020 and 2021, the company deferred for recovery from customers $27 million and $100 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020 and 2021, the company deferred $24.7 million and $26 million as a regulatory liability, respectively. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.8 percent Actual return on common equity (i) (j) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Yr. 2 – 8.48 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. In January 2022, CECONY filed a request with the NYSPSC for a gas rate increase of $503 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filed gas revenue requirement includes additional depreciation expense of $48 million. Included in this increase is the impact of the company’s proposal to decrease the service lives for the longer-lived gas accounts by five years. The filing includes supplemental information regarding gas rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $234 million and $218 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2021, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020 and 2021, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets and $32 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020 and by $0.6 million in 2021. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020 and 2021, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. In October 2021, O&R, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for new electric and gas rate plans for the three-year period January 2022 through December 2024 (the Joint Proposal). The Joint Proposal is subject to NYSPSC approval. The Joint Proposal includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ( $2.8 million ); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. The following tables contain a summary of the current and proposed rate plans. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $1

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases	Leases The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognize lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Operating lease cost $86 $85 $66 $65 Operating lease cash flows $80 $79 $63 $61 As of December 31, 2021, assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $4 million and $2 million, respectively. As of December 31, 2020, assets recorded as finance leases were $3 million for Con Edison and $2 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. For the twelve months ended December 31, 2021 and 2020, finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $58 million and $12 million, respectively, for the twelve months ended December 31, 2021 and $23 million and $11 million, respectively, for the twelve months ended December 31, 2020. Other information related to leases for Con Edison and CECONY at December 31, 2021 and 2020 was as follows: Con Edison CECONY 2021 2020 2021 2020 Weighted Average Remaining Lease Term: Operating leases 18.5 years 19.1 years 12.1 years 13.0 years Finance leases 7.1 years 7.3 years 3.1 years 4.0 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.5% 3.6% Finance leases 1.8% 1.8% 1.1% 1.3% Future minimum lease payments under non-cancellable leases at December 31, 2021 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2022 $81 $— $60 $— 2023 77 — 59 — 2024 77 1 59 1 2025 78 — 60 — 2026 76 — 59 — All years thereafter 877 1 394 — Total future minimum lease payments $1,266 $2 $691 $1 Less: imputed interest (436) — (139) — Total $830 $2 $552 $1 Reported as of December 31, 2021 Operating lease liabilities (current) $113 $— $90 $— Operating lease liabilities (noncurrent) 717 — 462 — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $830 $2 $552 $1 At December 31, 2021, the Companies had an additional operating lease agreement that had not yet commenced, for an asset under construction at the Clean Energy Businesses, for which the present value of lease payments is $6 million. This lease is expected to commence within one year, with a lease term of approximately 45 years.
Leases	Leases The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognize lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Operating lease cost $86 $85 $66 $65 Operating lease cash flows $80 $79 $63 $61 As of December 31, 2021, assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $4 million and $2 million, respectively. As of December 31, 2020, assets recorded as finance leases were $3 million for Con Edison and $2 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. For the twelve months ended December 31, 2021 and 2020, finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $58 million and $12 million, respectively, for the twelve months ended December 31, 2021 and $23 million and $11 million, respectively, for the twelve months ended December 31, 2020. Other information related to leases for Con Edison and CECONY at December 31, 2021 and 2020 was as follows: Con Edison CECONY 2021 2020 2021 2020 Weighted Average Remaining Lease Term: Operating leases 18.5 years 19.1 years 12.1 years 13.0 years Finance leases 7.1 years 7.3 years 3.1 years 4.0 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.5% 3.6% Finance leases 1.8% 1.8% 1.1% 1.3% Future minimum lease payments under non-cancellable leases at December 31, 2021 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2022 $81 $— $60 $— 2023 77 — 59 — 2024 77 1 59 1 2025 78 — 60 — 2026 76 — 59 — All years thereafter 877 1 394 — Total future minimum lease payments $1,266 $2 $691 $1 Less: imputed interest (436) — (139) — Total $830 $2 $552 $1 Reported as of December 31, 2021 Operating lease liabilities (current) $113 $— $90 $— Operating lease liabilities (noncurrent) 717 — 462 — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $830 $2 $552 $1 At December 31, 2021, the Companies had an additional operating lease agreement that had not yet commenced, for an asset under construction at the Clean Energy Businesses, for which the present value of lease payments is $6 million. This lease is expected to commence within one year, with a lease term of approximately 45 years.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2021
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The Companies test goodwill for impairment at least annually or whenever there is a triggering event. There is an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying a quantitative goodwill impairment test. The quantitative goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss shall be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. Con Edison has recorded goodwill related to the O&R merger, the acquisition of a portion of Honeoye, and the acquisitions of a residential solar company and a battery storage company by the Clean Energy Businesses. In 2021 and 2020, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger and determined that it was not impaired. For the impairment test, $245 million and $161 million of goodwill were allocated to CECONY and O&R, respectively. In 2021, the Companies performed the qualitative assessment for goodwill related to the O&R merger. In 2021 and 2020, Con Edison completed impairment tests for goodwill of $8 million related to Honeoye, $14 million related to the residential solar company acquired by the Clean Energy Businesses and $18 million related to the battery storage company acquired by the Clean Energy Businesses. In 2021, Con Edison determined, based on a discounted cash flow analysis, that $7 million of goodwill was impaired related to Honeoye, $5 million of which was attributed to CET Gas and $2 million of which was attributed to CECONY.

Income Tax

Income Tax	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Tax	Income Tax In response to the economic impacts of the COVID-19 pandemic, the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was signed into law on March 27, 2020. The CARES Act provided relief to corporate taxpayers by permitting a five-year carryback of net operating losses (NOLs) for tax years 2018, 2019 and 2020, temporarily removing the 80 percent limitation when applying the NOLs to carryback years, increased the 30 percent limitation on interest deductibility to 50 percent of adjusted taxable income for tax years 2019 and 2020, and provided for certain employee retention tax credits and refunds for eligible employers. Under the CARES Act, Con Edison carried back its $29 million NOL from tax year 2018 to tax year 2013 generating a $2.5 million net tax refund for which a tax receivable was established in 2020. In addition, Con Edison recognized a discrete income tax benefit of $4 million in 2020, due to the higher federal statutory tax rate in 2013. The 2018 federal NOL was recorded at 21 percent and was carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This income tax benefit was primarily recognized at the Clean Energy Businesses. The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 State Current $14 $7 $(12) $1 $6 $22 Deferred 79 50 96 106 97 68 Federal Current 43 (2) — 121 41 185 Deferred 61 42 219 21 73 63 Amortization of investment tax credits (7) (7) (7) (3) (2) (3) Total income tax expense $190 $90 $296 $246 $215 $335 The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 0 Deferred tax liabilities: Property basis differences $8,298 $7,985 $7,213 $6,901 Regulatory assets: Unrecognized pension and other postretirement costs 36 910 31 861 Environmental remediation costs 264 243 241 222 Deferred storm costs 33 31 — — Other regulatory assets 640 536 609 508 Operating lease right-of-use asset 204 220 155 165 Pension Asset Reserve 478 — 471 — Equity investments — 46 — — Other 30 — — — Total deferred tax liabilities $9,983 $9,971 $8,720 $8,657 Deferred tax assets: Accrued pension and other postretirement costs $218 $504 $188 $427 Regulatory liabilities: Future income tax 554 617 517 579 Other regulatory liabilities 727 656 620 570 Superfund and other environmental costs 264 241 238 219 Asset retirement obligations 177 178 141 143 Operating lease liabilities 195 211 155 165 Loss carryforwards 144 164 38 34 Tax credits carryforward 946 1,022 — — Valuation allowance (22) (22) — — Equity investments 34 — — — Other — 59 42 127 Total deferred tax assets 3,237 3,630 1,939 2,264 Net deferred tax liabilities $6,746 $6,341 $6,781 $6,393 Unamortized investment tax credits 127 134 15 18 Net deferred tax liabilities and unamortized investment tax credits $6,873 $6,475 $6,796 $6,411 Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows: Con Edison CECONY (% of Pre-tax income) 2021 2020 2019 2021 2020 2019 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income tax benefit 4 4 4 5 5 5 Taxes attributable to noncontrolling interests 3 (1) (1) — — — Cost of removal 2 2 1 1 1 1 Other plant-related items (1) (1) (1) (1) (1) (1) Amortization of excess deferred federal income taxes (12) (14) (4) (11) (12) (4) Renewable energy credits (2) (3) (2) — — — Research and development credits (1) — (1) — — (1) Other — (1) — — 1 — Effective tax rate 14 % 7 % 17 % 15 % 15 % 21 % At December 31, 2021, Con Edison had $946 million in general business tax credit carryovers (primarily renewable energy tax credits). If unused, these general business tax credit carryovers will begin to expire in 2034. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance was provided, as it is more likely than not that the deferred tax asset will be realized. At December 31, 2021, Con Edison had a New York State NOL of approximately $1.13 billion, primarily as a result of higher accelerated state tax depreciation. A deferred tax asset has been recognized for these New York State NOL carryforwards that will begin to expire, if unused, in 2038 and no valuation allowance was provided; as it is more likely than not that the deferred tax asset will be realized. In addition, Con Edison has a $5 million valuation allowance against the New York City NOL deferred tax asset of approximately $17 million. Con Edison also has a $21.5 million valuation allowance for other state NOL carryforwards; as it is not more likely than not that the deferred tax asset will be realized. In December 2019, the Federal government issued final regulations providing guidance on provisions in the TCJA allowing for full expensing of qualified plant additions. These provisions, which Con Edison adopted under the proposed regulations of August 2018, allowed the Utilities a full expense tax deduction for plant additions in the fourth quarter of 2017, and the Utilities continue additional first year depreciation transition rules for plant additions placed in service in tax years beginning in 2018, under long-term construction contracts entered into before September 28, 2017. The impact on the Utilities of these regulations is discussed above. In November 2018, the Federal government issued, and Con Edison adopted, proposed regulations providing guidance on the tax deductibility of interest expense under the TCJA. The TCJA generally provides for the continued deductibility of interest expense by regulated public utilities and may limit the deduction for interest expense by most non-utility businesses to 30 percent of adjusted taxable income (which resembles earnings before interest, taxes, depreciation and amortization).The regulations provide an annual safe harbor test that if at least 90 percent of consolidated plant assets consist of utility property, the entire consolidated group will be treated as a regulated public utility, and all of the consolidated group’s interest expense will be currently tax deductible. For 2018, Con Edison met the 90 percent safe harbor test and its deduction for interest expense was not limited. For 2019, Con Edison did not meet the 90 percent safe harbor test, however, its deduction for interest expense was not limited as a percentage of adjusted taxable income. In 2020, the federal government issued final regulations under the TCJA. Under the CARES Act, the limit of the deductible interest expense as a percentage of adjusted taxable income increased from 30 percent to 50 percent and accordingly, all of Con Edison’s interest expense in 2020 will be tax deductible. In 2021, the limit of the deductible interest expense as a percentage of adjustable taxable income returned to 30 percent; however, Con Edison’s deduction for interest expense was not limited. Qualifying consolidated groups would not be entitled to the full expensing provisions in the TCJA noted above. The safe harbor rules do not apply to partnerships in which Con Edison and its subsidiaries are a partner. In April 2021, NY State passed a law that increased the corporate franchise tax rate on business income from 6.5% to 7.25%, retroactive to January 1, 2021, for taxpayers with taxable income greater than $5 million. The law also reinstated the business capital tax at 0.1875%, not to exceed an annual maximum tax liability of $5 million per taxpayer. NY State requires a corporate franchise taxpayer to calculate and pay the highest amount of tax under the three alternative methods: a tax on business income; a tax on business capital; or a fixed dollar minimum. The provisions to increase the corporate franchise tax rate and reinstate a business capital tax are scheduled to expire after 2023 and are not expected to have a material impact on the Companies’ financial position, results of operations or liquidity. Uncertain Tax Positions Under the accounting rules for income taxes, the Companies are not permitted to recognize the tax benefit attributable to a tax position unless such position is more likely than not to be sustained upon examination by taxing authorities, including resolution of any related appeals and litigation processes, based solely on the technical merits of the position. A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Balance at January 1, $14 $13 $6 $3 $2 $4 Additions based on tax positions related to the current year 3 — 1 2 — 1 Additions based on tax positions of prior years 2 1 10 1 1 — Reductions for tax positions of prior years (2) — (2) (1) — (1) Reductions from expiration of statute of limitations — — — — — — Settlements — — (2) — — (2) Balance at December 31, $17 $14 $13 $5 $3 $2 At December 31, 2021, the estimated liability for uncertain tax positions for Con Edison was $17 million ($5 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $12 million of various federal and state uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce Con Edison's effective tax rate. The amount related to CECONY is $3 million, which, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $17 million ($16 million, net of federal taxes) with $5 million attributable to CECONY. The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. For the year ended December 31, 2021, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2021 and 2020, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets. Con Edison's federal tax return for 2020 remains under examination. State and local income tax returns remain open for examination in NY State for tax years 2010 through 2020, in NJ for tax years 2017 through 2020 and in New York City for tax years 2017 through 2020.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The following table presents, for the years ended December 31, 2021, 2020 and 2019, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2021 2020 2019 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $8,736 $70 $8,806 $8,026 $77 $8,103 $7,913 $149 $8,062 Gas 2,324 54 2,378 1,998 38 2,036 2,097 35 2,132 Steam 519 13 532 494 14 508 610 17 627 Total CECONY $11,579 $137 $11,716 $10,518 $129 $10,647 $10,620 $201 $10,821 O&R Electric 691 (10) 681 619 10 629 627 7 634 Gas 265 (5) 260 224 9 233 247 12 259 Total O&R $956 $(15) $941 $843 $19 $862 $874 $19 $893 Clean Energy Businesses Renewables 683 — 683 609 — 609 575 — 575 Energy services 234 — 234 52 — 52 71 — 71 Other — 105 105 — 75 75 — 211 211 Total Clean Energy Businesses $917 $105 $1,022 $661 $75 $736 $646 $211 $857 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (7) (7) — (3) (3) — (1) (1) Total Con Edison $13,456 $220 $13,676 $12,026 $220 $12,246 $12,144 $430 $12,574 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their NY electric and gas rate plans, as well as net earnings adjustment mechanisms (EAMs) and positive incentives primarily for achieving energy efficiency goals (see "Rate Plans" in Note B), and for 2021 recognition of late payment charges and fees that were not billed (LPCs) for the years ended December 31, 2020 and 2021 and for which recovery was granted by the NYSPSC. See "COVID-19 Regulatory Matters" in Note B and "Utilities' Assessment of Late Payment Charges" below. The amount of revenue recognized under such alternative revenue programs for 2021 includes $48 million, $34 million and $74 million for CECONY's revenue decoupling mechanisms, net EAMs, and LPCs, respectively, and $(18) million, $2 million and $4 million for O&R's revenue decoupling mechanisms, net EAMs, and LPCs, respectively. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Parent company and consolidation adjustments. Revenues are recorded as energy is delivered, generated or services are provided and billed to customers, except for services under percentage-of-completion contracts. Amounts billed are recorded in accounts receivable - customers, with payment generally due the following month. Con Edison’s and the Utilities’ accounts receivable - customers balance also reflects the Utilities’ purchase of receivables from energy service companies to support retail choice programs. Accrued revenues not yet billed to customers are recorded as accrued unbilled revenues. The Utilities have the obligation to deliver electricity, gas and steam energy to their customers. As the energy is immediately available for use upon delivery to the customer, the energy and its delivery are identifiable as a single performance obligation. The Utilities recognize revenues as this performance obligation is satisfied over time as the Utilities deliver, and the customers simultaneously receive and consume, the energy. The amount of revenues recognized reflects the consideration the Utilities expect to receive in exchange for delivering the energy. Under their tariffs, the transaction price for full-service customers includes the Utilities’ energy cost and for all customers includes delivery charges determined based on customer class and in accordance with established tariffs and guidelines of the NYSPSC or the NJBPU, as applicable. Accordingly, there is no unsatisfied performance obligation associated with these customers. The transaction price is applied to the Utilities’ revenue generating activities through the customer billing process. Because energy is delivered over time, the Utilities use output methods that recognize revenue based on direct measurement of the value transferred, such as units delivered, which provides an accurate measure of value for the energy delivered. The Utilities accrue revenues at the end of each month for estimated energy delivered but not yet billed to customers. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Clean Energy Businesses recognize revenue for the sale of energy from renewable electric projects as energy is generated and billed to counterparties; accrue revenues at the end of each month for energy generated but not yet billed to counterparties; and recognize revenue as energy is delivered and services are provided for managing energy supply assets leased from others and managing the dispatch, fuel requirements and risk management activities for generating plants and merchant transmission in the northeastern United States. The Clean Energy Businesses also recognize revenue for providing energy-efficiency services to government and commercial customers, and recognize revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition. Clean Energy Businesses' Use of the Percentage-of-Completion Method Sales and profits on each percentage-of-completion contract are recorded each month based on the ratio of actual cumulative costs incurred to the total estimated costs at completion of the contract, multiplied by the total estimated contract revenue, less cumulative revenues recognized in prior periods (the ‘‘cost-to-cost’’ method). The impact of revisions of contract estimates, which may result from contract modifications, performance or other reasons, are recognized on a cumulative catch-up basis in the period in which the revisions are made. 2021 2020 2019 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $11 $41 $29 $17 $29 $20 Additions (c) 242 — 88 31 86 1 Subtractions (c) 218 34 (d) 106 7 (d) 86 4 (d) Ending balance as of December 31, $35 $7 $11 $41 $29 $17 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. (d) Of the subtractions from unearned revenue, $34 million, $7 million and $4 million were included in the balances as of January 1, 2021, 2020, and 2019, respectively. As of December 31, 2021, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $120 million, of which $81 million will be recognized within the next two years, and the remaining $39 million will be recognized pursuant to long-term service and maintenance agreements. Utilities' Assessment of Late Payment Charges In March 2020, the Utilities began suspending new late payment charges and certain other fees for all customers. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In November 2021, the NYSPSC issued an order establishing a surcharge recovery mechanism for CECONY to collect, commencing December 1, 2021 through December 31, 2022, $43 million and $7 million for electric and gas, respectively, of late payment charges and fees that were not billed for the year ended December 31, 2020. The company recorded such amounts as revenue for the year ended December 31, 2021, as permitted under the accounting rules for regulated utilities, and also accrued such amounts as a current asset at December 31, 2021. Pursuant to the November 2021 order, the company also established a recovery mechanism for CECONY to collect, commencing January 2023 through December 2023, $19 million and $4 million for electric and gas, respectively, of late payment charges and fees that were not billed for the year ended December 31, 2021 and the company recorded such amounts as revenue for the year ended December 31, 2021, as permitted under the accounting rules for regulated utilities, and also accrued such amounts as a current asset at

Current Expected Credit Losses

Current Expected Credit Losses	12 Months Ended
	Dec. 31, 2021
Credit Loss [Abstract]
Current Expected Credit Losses	Current Expected Credit Losses In January 2020, the Companies adopted Accounting Standards Update (ASU) 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments”. Allowance for Uncollectible Accounts The Utilities’ “Account receivable – customers” balance consists of utility bills due (bills are generally due the month following billing) from customers who have energy delivered, generated, or services provided by the Utilities. The balance also reflects the Utilities’ purchase of receivables from energy service companies to support the retail choice programs. “Other receivables” balance generally reflects costs billed by the Utilities for goods and services provided to external parties, such as accommodation work for private parties and certain governmental entities, real estate rental and pole attachments. The Clean Energy Businesses’ other receivables balance includes bills related to the sale of energy from renewable electric projects. The Clean Energy Businesses’ customer accounts receivable balance generally reflects the management of energy supply assets, energy-efficiency services to government and commercial customers, and the engineering, procurement, and construction services of renewable energy projects. The Clean Energy Businesses calculate an allowance for uncollectible accounts related to their energy services customers based on an aging and customer-specific analysis. The amount of such reserves was not material at December 31, 2021 and December 31, 2020. The Companies develop expected loss estimates using past events data and consider current conditions and future reasonable and supportable forecasts. Changes to the Utilities’ reserve balances that result in write-offs of customer accounts receivable balances above existing rate allowances are not reflected in rates during the term of the current rate plans. For the Utilities’ customer accounts receivable allowance for uncollectible accounts, past events considered include write-offs relative to customer accounts receivable; current conditions include macro-and micro-economic conditions related to trends in the local economy, bankruptcy rates and aged customer accounts receivable balances, among other factors; and forecasts about the future include assumptions related to the level of write-offs and recoveries. Generally, the Utilities write off customer accounts receivable as uncollectible 90 days after the account is turned off for non-payment, or the account is closed during the collection process. See "COVID-19 Regulatory Matters" in Note B. Other receivables allowance for uncollectible accounts is calculated based on a historical average of collections relative to total other receivables, including current receivables. Current macro- and micro-economic conditions are also considered when calculating the current reserve. Probable outcomes of pending litigation, whether favorable or unfavorable to the Companies, are also included in the consideration. During the years ended December 31, 2021 and 2020, the potential economic impact of the COVID-19 pandemic was also considered in forward-looking projections related to write-off and recovery rates and resulted in increases to the allowance for uncollectible accounts. The increases to the allowance for customer uncollectible accounts for Con Edison and CECONY were $169 million and $166 million, respectively, for the year ended December 31, 2021. The increases to the allowance for uncollectible accounts for Con Edison and CECONY were $78 million and $73 million for the year ended December 31, 2020. Customer accounts receivable and the associated allowance for uncollectible accounts are included in the line “Accounts receivable – customers” on the Companies’ consolidated balance sheets. Other receivables and the associated allowance for uncollectible accounts are included in “Other receivables” on the consolidated balance sheets. The table below presents a rollforward by major portfolio segment type for the years ended December 31, 2021 and 2020: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2021 2020 2021 2020 2021 2020 2021 2020 Allowance for credit losses Beginning Balance at January 1, $148 $70 $7 $4 $138 $65 $4 $3 Recoveries 14 8 1 — 12 6 1 — Write-offs (91) (54) (2) (2) (86) (50) (1) (1) Reserve adjustments 246 124 16 5 240 117 15 2 Ending Balance December 31, $317 $148 $22 $7 $304 $138 $19 $4

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Stock-Based Compensation	Stock-Based Compensation The Companies may compensate employees and directors with, among other things, stock options, stock units, restricted stock units and contributions to the stock purchase plan. The Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2003 (2003 LTIP), and the Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2013 (2013 LTIP), are collectively referred to herein as the LTIP. The LTIP provides for, among other things, awards to employees of restricted stock units and stock options and, to Con Edison’s non-employee directors, stock units. Existing awards under the 2003 LTIP continue in effect, however no new awards may be issued under the 2003 LTIP. The 2013 LTIP provides for awards for up to five million shares of common stock. During the years ended December 31, 2021, 2020, and 2019, equity awards were granted under the 2013 LTIP. Shares of Con Edison common stock used to satisfy the Companies’ obligations with respect to stock-based compensation may be new shares (authorized, but unissued) or treasury shares (existing treasury shares or shares purchased in the open market). The shares used during the year ended December 31, 2021 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2022. The Companies recognized stock-based compensation expense using a fair value measurement method. The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2021, 2020 and 2019: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Performance-based restricted stock $23 $7 $36 $19 $6 $30 Time-based restricted stock 2 1 2 2 1 2 Non-employee director deferred stock compensation 3 2 2 3 2 2 Stock purchase plan 7 7 7 7 7 6 Total $35 $17 $47 $31 $16 $40 Income tax benefit $10 $5 $13 $9 $4 $11 Restricted Stock and Stock Units Restricted stock and stock unit awards under the LTIP have been made as follows: (i) awards that provide for adjustment of the number of units (performance-restricted stock units or Performance RSUs) to certain officers and employees; (ii) time-based awards to certain employees; and (iii) awards to non-employee directors. Restricted stock and stock units awarded represent the right to receive, upon vesting, shares of Con Edison common stock, or, except for units awarded under the directors’ plan, the cash value of shares or a combination thereof. The number of units in each annual Performance RSU award is subject to adjustment as follows: (i) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 200 percent, based on Con Edison’s total shareholder return relative to a specified peer group during a specified performance period (the TSR portion); and (ii) 50 percent of the units awarded will be multiplied by factors that may range from 0 to 200 percent, based on determinations made in connection with the Companies’ annual incentive plans or, with respect to certain executive officers, actual performance as compared to certain performance measures during a specified performance period (the non-TSR portion). Performance RSU awards generally vest upon completion of the performance period. Performance against the established targets is recomputed each reporting period as of the earlier of the reporting date and the vesting date. The TSR portion applies a Monte Carlo simulation model, and the non-TSR portion is the product of the market price at the end of the period and the average non-TSR determination over the vesting period. Performance RSUs are “liability awards” because each Performance RSU represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, changes in the fair value of the Performance RSUs are reflected in net income. The assumptions used to calculate the fair value of the awards were as follows: 2021 2020 2019 Risk-free interest rate (a) 0.39% - 0.73% 0.10% - 0.13% 1.58% -1.59% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 17.25% - 31.42% 30.16% - 40.95% 12.89% - 15.51% (a) The risk-free rate is based on the U.S. Treasury zero-coupon yield curve. (b) The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur. (c) Based on historical experience. The Companies would reevaluate this assumption if market conditions or business developments would reasonably indicate that future volatility might differ materially from historical experience. A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2021 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Portion (b) Non-TSR Portion (c) Units TSR Portion (b) Non-TSR Portion (c) Non-vested at December 31, 2020 901,524 $70.11 $81.83 686,471 $70.15 $81.80 Granted 401,100 74.46 71.04 301,087 74.23 71.25 Vested (301,600) 67.27 76.37 (227,411) 66.82 76.48 Forfeited (16,296) 75.23 79.78 (15,869) 75.21 79.84 Non-vested at December 31, 2021 984,728 $72.67 $79.14 744,278 $72.71 $79.20 (a) The TSR and non-TSR Portions each account for 50 percent of the awards’ value. (b) Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting. (c) Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting. The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding at December 31, 2021 is $33 million, including $27 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY. Con Edison and CECONY paid cash of $8 million and $7 million in 2021, $21 million and $18 million in 2020, and $24 million and $22 million in 2019, respectively, to settle vested Performance RSUs. In accordance with the accounting rules for stock compensation, for time-based awards, the Companies are accruing a liability and recognizing compensation expense based on the market value of a common share throughout the vesting period. The vesting period for awards is three years and is based on the employee’s continuous service to Con Edison. Prior to vesting, the awards are subject to forfeiture in whole or in part under certain circumstances. The awards are “liability awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, prior to vesting, changes in the fair value of the units are reflected in net income. A summary of changes in the status of time-based awards during the year ended December 31, 2021 is as follows: Con Edison CECONY Units Weighted Average Grant Date Fair Value Units Weighted Average Grant Date Fair Value Non-vested at December 31, 2020 67,438 $80.40 62,838 $80.42 Granted 17,150 74.80 16,200 74.80 Vested (21,121) 77.96 (19,588) 77.95 Forfeited (1,847) 80.23 (1,580) 79.89 Non-vested at December 31, 2021 61,620 $79.68 57,870 $79.70 The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2021 for Con Edison and CECONY is $2 million, and is expected to be recognized over a weighted average period of one year. Con Edison and CECONY paid cash of $1 million in 2021, 2020 and 2019, to settle vested time-based awards. Under the LTIP, each non-employee director receives stock units, which are deferred until the director’s separation from service or another date specified by the director. Each director may also elect to defer all or a portion of their cash compensation into additional stock units, which are deferred until the director’s termination of service or another date specified by the director. Non-employee directors’ stock units issued under the LTIP are considered “equity awards,” because they may only be settled in shares. Directors immediately vest in units issued to them. The fair value of the units is determined using the closing price of Con Edison’s common stock on the business day immediately preceding the date of issue. In the year ended December 31, 2021, approximately 36,000 units were issued at a weighted average grant date price of $77.53. Stock Purchase Plan The Stock Purchase Plan, which was approved by shareholders in 2004 and 2014, provides for the Companies to contribute up to $1 for each $9 invested by their directors, officers or employees to purchase Con Edison common stock under the plan. Eligible participants may invest up to $25,000 during any calendar year (subject to an additional limitation for officers and employees of not more than 20 percent of their pay). Dividends paid on shares held under the plan are reinvested in additional shares unless otherwise directed by the participant. Participants in the plan immediately vest in shares purchased by them under the plan. Prior to September 1, 2020, the fair value of the shares of Con Edison common stock purchased under the plan was calculated using the average of the high and low composite sale prices at which shares were traded at the New York Stock Exchange on the trading day immediately preceding such purchase dates. During 2020, the plan was amended and as a result of the amendment, the fair value of the shares of Con Edison common stock purchased after September 1, 2020 under the plan was calculated using the closing price at which shares were traded on the New York Stock Exchange on the last business day of the month for all shares purchased during the month. During 2021, 2020 and 2019, 957,866, 836,984 and 747,899 shares were purchased under the Stock Purchase Plan at a weighted average price of $73.38, $79.82 and $85.45 per share, respectively.

Financial Information by Busine

Financial Information by Business Segment	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment The business segments of each of the Companies, which are its operating segments, were determined based on management’s reporting and decision-making requirements in accordance with the accounting rules for segment reporting. Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. All revenues of these business segments are from customers located in the United States of America. Also, all assets of the business segments are located in the United States of America. The accounting policies of the segments are the same as those described in Note A. Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided. The financial data for the business segments are as follows: As of and for the Year Ended December 31, 2021 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,806 $18 $1,286 $1,802 $(84) $542 $151 $36,260 $2,189 Gas 2,378 8 326 646 (16) 179 110 13,748 1,126 Steam 532 74 93 12 (8) 41 (9) 2,647 103 Consolidation adjustments — (100) — — — — — — — Total CECONY $11,716 $— $1,705 $2,460 ($108) $762 $252 $52,655 $3,418 O&R Electric $681 $— $69 $100 $(8) $27 $13 $2,123 $147 Gas 260 — 26 50 (4) 15 8 1,169 70 Other — — — — — — — — — Total O&R $941 $— $95 $150 $(12) $42 $21 $3,292 $217 Clean Energy Businesses $1,022 $— $231 $236 $(10) $68 $44 $6,554 $298 Con Edison Transmission 4 — 1 (16) (407) 9 3 249 31 Other (b) (7) — — (4) (1) 24 20 366 — Total Con Edison $13,676 $— $2,032 $2,826 $(538) $905 $340 $63,116 $3,964 As of and for the Year Ended December 31, 2020 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,103 $18 $1,214 $1,731 $(134) $535 $130 $35,673 $2,080 Gas 2,036 7 294 574 (25) 164 102 12,678 1,044 Steam 508 74 90 5 (12) 40 (14) 2,616 122 Consolidation adjustments — (99) — — — — — — — Total CECONY $10,647 $— $1,598 $2,310 $(171) $739 $218 $50,967 $3,246 O&R Electric $629 $— $65 $99 $(10) $26 $13 $2,097 $159 Gas 233 — 25 48 (4) 15 8 1,150 61 Other — — — — — — — — — Total O&R $862 $— $90 $147 $(14) $41 $21 $3,247 $220 Clean Energy Businesses $736 $— $231 $215 $4 $196 $(43) $6,848 $616 Con Edison Transmission 4 — 1 (8) (215) 18 — 1,348 3 Other (b) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 As of and for the Year Ended December 31, 2019 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $8,062 $17 $1,053 $1,758 $(28) $539 $239 $32,988 $1,851 Gas 2,132 7 231 528 (4) 147 99 11,090 1,078 Steam 627 70 89 62 (3) 42 4 2,479 91 Consolidation adjustments — (94) — — — — — — — Total CECONY $10,821 $— $1,373 $2,348 $(35) $728 $342 $46,557 $3,020 O&R Electric $634 $— $60 $98 $(7) $27 $15 $2,130 $142 Gas 259 — 24 41 (4) 14 6 876 61 Other — — — — — — — — — Total O&R $893 $— $84 $139 $(11) $41 $21 $3,006 $203 Clean Energy Businesses $857 $— $226 $202 $5 $186 $(58) $6,528 $248 Con Edison Transmission 4 — 1 (6) 104 25 1 1,618 205 Other (b) (1) — — (7) (12) 11 (6) 370 — Total Con Edison $12,574 $— $1,684 $2,676 $51 $991 $300 $58,079 $3,676 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $(150) million, $(103) million and $(4) million in 2021, 2020 and 2019, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(6) million, $(3) million and $(7) million in 2021, 2020 and 2019, respectively. (b) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. These are economic hedges, for which the Utilities and the Clean Energy Business do not elect hedge accounting. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuances and borrowings. Derivatives are recognized on the consolidated balance sheet at fair value (see Note R), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules. The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2021 and 2020 were: (Millions of Dollars) 2021 2020 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $285 $(158) $127 (b) $44 $14 $58 (b) Noncurrent 90 (13) 77 22 35 57 (d) Total fair value of derivative assets $375 $(171) $204 $66 $49 $115 Fair value of derivative liabilities Current $(289) $137 $(152) (c) $(225) $(13) $(238) (d) Noncurrent (94) 10 (84) (c) (207) (33) (240) (d) Total fair value of derivative liabilities $(383) $147 $(236) $(432) $(46) $(478) Net fair value derivative assets/(liabilities) $(8) $(24) $(32) $(366) $3 $(363) CECONY Fair value of derivative assets Current $135 $(64) $71 (b) $20 $(12) $8 (b) Noncurrent 71 (15) 56 16 (8) 8 Total fair value of derivative assets $206 $(79) $127 $36 $(20) $16 Fair value of derivative liabilities Current $(131) $43 $(88) $(174) $11 $(163) Noncurrent (50) 10 (40) (114) 9 (105) Total fair value of derivative liabilities $(181) $53 $(128) $(288) $20 $(268) Net fair value derivative assets/(liabilities) $25 ($26) $(1) $(252) $— $(252) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2021 and 2020, margin deposits for Con Edison ($1 million and $3 million, respectively) and CECONY (an immaterial amount and $3 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer. (d) Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041. The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. See "Recoverable Energy Costs" in Note A. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or regulatory liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. The Clean Energy Businesses record realized and unrealized gains and losses on their derivative contracts in gas purchased for resale and non-utility revenue in the reporting period in which they occur. The Clean Energy Businesses record changes in the fair value of their interest rate swaps in other interest expense at the end of each reporting period. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices and interest rates. The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the years ended December 31, 2021 and 2020: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2021 2020 2021 2020 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $134 $(26) $124 $(27) Noncurrent Deferred derivative gains 57 — 51 — Total deferred gains/(losses) $191 $(26) $175 $(27) Current Deferred derivative losses $49 $(63) $43 $(64) Current Recoverable energy costs 3 (201) — (177) Noncurrent Deferred derivative losses 70 (37) 66 (36) Total deferred gains/(losses) $122 $(301) $109 $(277) Net deferred gains/(losses) $313 $(327) $284 $(304) Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $18 $(2) $— $— Non-utility revenue 3 7 — — Other operations and maintenance expense 5 (3) 5 (3) Other interest expense 52 (65) — — Total pre-tax gain/(loss) recognized in income $78 $(63) $5 $(3) The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2021: Electric Energy Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 26,982,370 42,333 253,195,063 3,696,000 CECONY 24,646,000 28,800 235,570,000 3,696,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the Clean Energy Businesses. Credit risk relates to the loss that may result from a counterparty’s nonperformance. The Companies use credit policies to manage this risk, including an established credit approval process, monitoring of counterparty limits, netting provisions within agreements, collateral or prepayment arrangements, credit insurance and credit default swaps. The Companies measure credit risk exposure as the replacement cost for open energy commodity and derivative positions plus amounts owed from counterparties for settled transactions. The replacement cost of open positions represents unrealized gains, net of any unrealized losses where the Companies have a legally enforceable right to offset. At December 31, 2021, Con Edison and CECONY had $406 million and $145 million of credit exposure in connection with open energy supply net receivables and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $91 million with independent system operators, $127 million with investment-grade counterparties, $53 million with non-investment grade/non-rated counterparties, and $135 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $66 million with commodity exchange brokers and $79 million with investment-grade counterparties. The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings. The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2021: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $158 $121 Collateral posted 170 170 Additional collateral (b) (downgrade one level from current ratings) 43 1 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 94 37 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $5 million at December 31, 2021. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset. (c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2021, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $66 million.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows: • Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange. • Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models. • Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value. For information on the measurement of Con Edison's investment in MVP, which was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2021 and 2020 are summarized below. 2021 2020 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $95 $260 $17 $(171) $201 $19 $42 $4 $53 $118 Interest rate swaps (a)(b)(c)(f) — 4 — — 4 — — — — — Other (a)(b)(d) 492 135 — — 627 431 126 — — 557 Total assets $587 $399 $17 $(171) $832 $450 $168 $4 $53 $675 Derivative liabilities: Commodity (a)(b)(c) $33 $266 $28 $(148) $179 $7 $296 $23 $46 $372 Interest rate swaps (a)(b)(c)(f) — 57 — — 57 — 106 — — 106 Total liabilities $33 $323 $28 $(148) $236 $7 $402 $23 $46 $478 CECONY Derivative assets: Commodity (a)(b)(c) $67 $138 $1 $(79) $127 $15 $20 $— $(16) $19 Other (a)(b)(d) 474 127 — — 601 411 120 — — 531 Total assets $541 $265 $1 $(79) $728 $426 $140 $— $(16) $550 Derivative liabilities: Commodity (a)(b)(c) $1 $172 $8 $(53) $128 $3 $274 $10 $(19) $268 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Con Edison and CECONY had $1 million of commodity derivative assets and $4 million and $3 million of commodity derivative liabilities, respectively, transferred from level 3 to level 2 during the year ended December 31, 2021 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2021 to less than three years as of December 31, 2021. Con Edison and CECONY had $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2020 to less than three years as of December 31, 2020. (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2021 and 2020, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. (f) See Note Q. The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives and interest rate swaps. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives and interest rate swaps. Fair value and changes in fair value of commodity derivatives and interest rate swaps are reported monthly to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer. Fair Value of Level 3 at December 31, 2021 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity $(6) Discounted Cash Flow Forward energy prices (a) $18.75-$82.40 per MWh (10) Discounted Cash Flow Forward capacity prices (a) $0.31-$12.93 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 5 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(20.27)-$83.04 per MWh Total Con Edison — Commodity $(11) CECONY — Commodity Electricity $(8) Discounted Cash Flow Forward capacity prices (a) $1.35-$12.93 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.52-$3.63 per MWh Total CECONY — Commodity $(7) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement. The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2021 and 2020 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Beginning balance as of January 1, $(19) $(16) $(10) $(6) Included in earnings (9) (10) (3) (5) Included in regulatory assets and liabilities 3 (7) 1 (4) Purchases 6 — — — Settlements 5 15 3 6 Transfer out of level 3 3 (1) 2 (1) Ending balance as of December 31, $(11) $(19) $(7) $(10) For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. See Note A. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Variable Interest Entities	Variable Interest EntitiesThe accounting rules for consolidation address the consolidation of a variable interest entity (VIE) by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. The Companies enter into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, the Companies retain or may retain a variable interest in these entities. CECONY CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partners, LP, a potential VIE. In 2021, a request was made of this counterparty for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments for this contract constitute CECONY's maximum exposure to loss with respect to the potential VIE. Clean Energy Businesses In June 2021, a subsidiary of the Clean Energy Businesses sold substantially all of its membership interest in a renewable electric project, and retained an equity interest of $11 million in the project, which is accounted for as an equity method investment. See Note W. The earnings of the project are determined using the hypothetical liquidation at book value (HLBV) method of accounting which resulted in a loss of $11 million pre-tax ($8 million after-tax) for the year ended December 31, 2021. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the renewable electric project is not held by the Clean Energy Businesses. In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement relating to certain projects (CED Nevada Virginia) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows will be allocated. CED Nevada Virginia is a consolidated entity in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of CED Nevada Virginia during construction of the projects, and upon commercial operation, is held by the Clean Energy Businesses. For the year ended December 31, 2021, the HLBV method of accounting for CED Nevada Virginia resulted in a $158 million loss ($119 million, after tax) for the tax equity investor and $155 million of income ($117 million, after tax) for Con Edison. In 2018, the Clean Energy Businesses completed its acquisition of Sempra Solar Holdings, LLC. Included in the acquisition were certain operating projects (Tax Equity Projects) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows are allocated. The Tax Equity Projects are consolidated entities in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of the Tax Equity Projects is held by the Clean Energy Businesses. Electricity generated by the Tax Equity Projects is sold to utilities and municipalities pursuant to long-term power purchase agreements. For the year ended December 31, 2021, the HLBV method of accounting for the Tax Equity Projects resulted in $6 million of income ($4 million, after tax) for the tax equity investor and $30 million of income ($24 million, after tax) for Con Edison. For the year ended December 31, 2020, the HLBV method of accounting for the Tax Equity Projects resulted in $43 million of income ($32 million, after tax) for the tax equity investor and a $6 million loss ($4 million, after tax) for Con Edison. Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. Refer to Use of Hypothetical Liquidation at Book Value in Note A. At December 31, 2021 and 2020, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar CED Nevada Virginia (c)(h) (Millions of Dollars) 2021 2020 2021 2020 2021 Non-utility property, less accumulated depreciation (f)(g) $275 $284 $431 $446 $643 Other assets 37 39 167 176 55 Total assets (a) $312 $323 $598 $622 $698 Other liabilities 14 13 74 71 315 Total liabilities (b) $14 $13 $74 $71 $315 (a) The assets of the Tax Equity Projects and CED Nevada Virginia represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects and CED Nevada Virginia represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $84 million and $82 million at December 31, 2021 and 2020, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $118 million and $134 million at December 31, 2021 and 2020, respectively. (f) Non-utility property is reduced by accumulated depreciation of $26 million for Great Valley Solar, $44 million for Copper Mountain - Mesquite Solar and $10 million for CED Nevada Virginia at December 31, 2021. (g) Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020. (h) CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $95 million at December 31, 2021. The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2021: Project Name Generating Capacity (a) (MW AC) Power Purchase Agreement Term in Years Year of Investment Location Maximum Millions of Dollars ) (b) Great Valley Solar (c) 200 15-20 2018 CA $214 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 NV and AZ 406 CED Nevada Virginia (c) 431 20-25 2021 NV and VA 288 (a) Represents ownership interest in the project. (b) Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (c) For the projects comprising Great Valley Solar, Copper Mountain Mesquite Solar and CED Nevada Virginia, refer to (d), (e) and (h) in the table above.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Companies recognize a liability at fair value for legal obligations associated with the retirement of long-lived assets in the period in which they are incurred, or when sufficient information becomes available to reasonably estimate the fair value of such legal obligations. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. The fair value of the asset retirement obligation liability is measured using expected future cash flows discounted at credit-adjusted risk-free rates, historical information, and where available, quoted prices from outside contractors. The Companies evaluate these assumptions underlying the asset retirement obligation liability on an annual basis or as frequently as needed. The Companies recorded asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings (other than the structures enclosing generating stations and substations), electric equipment and steam and gas distribution systems. The Companies also recorded asset retirement obligations relating to gas and oil pipelines abandoned in place and municipal infrastructure support. The Companies did not record an asset retirement obligation for the removal of asbestos associated with the structures enclosing generating stations and substations. For these building structures, the Companies were unable to reasonably estimate their asset retirement obligations because the Companies were unable to estimate the undiscounted retirement costs or the retirement dates and settlement dates. The amount of the undiscounted retirement costs could vary considerably depending on the disposition method for the building structures, and the method has not been determined. The Companies anticipate continuing to use these building structures in their businesses for an indefinite period, and so the retirement dates and settlement dates are not determinable. Con Edison recorded asset retirement obligations for the removal of the Clean Energy Businesses’ solar and wind equipment related to projects located on property that is not owned by them and the term of the arrangement is finite including any renewal options. Con Edison did not record asset retirement obligations for the Clean Energy Businesses’ projects that are located on property that is owned by them because they expect that the equipment will continue to generate electricity at these facilities long past the manufacturer’s warranty at minimal operating expense. Therefore, Con Edison was unable to reasonably estimate the retirement date of this equipment. The Utilities include in depreciation rates the estimated removal costs, less salvage, for utility plant assets. The amounts related to removal costs that are associated with asset retirement obligations are classified as an asset retirement liability. Pursuant to accounting rules for regulated operations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities. Accretion and depreciation expenses related to removal costs that represent legal asset retirement obligations are applied against the Companies’ regulatory liabilities. Asset retirement costs that are recoverable from customers are recorded as regulatory liabilities to reflect the timing difference between costs recovered through the rate-making process and recognition of costs. At December 31, 2021, the liabilities for asset retirement obligations of Con Edison and CECONY were $577 million and $504 million, respectively. At December 31, 2020, the liabilities for asset retirement obligations of Con Edison and CECONY were $576 million and $508 million, respectively. The change in liabilities at December 31, 2021 was due to changes in estimated cash flows of $58 million and $55 million for Con Edison and CECONY, respectively, and accretion expense of $18 million and $15 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $75 million and $74 million for Con Edison and CECONY, respectively. The change in liabilities at December 31, 2020 was due to changes in estimated cash flows of $191 million and $186 million for Con Edison and CECONY, respectively, and accretion expense of $16 million and $13 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $56 million and $53 million for Con Edison and CECONY, respectively. At December 31, 2021, Con Edison and CECONY recorded reductions of $87 million and $85 million, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense. At December 31, 2020, Con Edison and CECONY recorded reductions of $49 million to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions The NYSPSC generally requires that the Utilities and Con Edison’s other subsidiaries be operated as separate entities. The Utilities and the other subsidiaries are required to have separate operating employees and operating officers of the Utilities may not be operating officers of the other subsidiaries. The Utilities may provide administrative and other services to, and receive such services from, Con Edison and its other subsidiaries only pursuant to cost allocation procedures approved by the NYSPSC. Transfers of assets between the Utilities and Con Edison or its other subsidiaries may be made only as approved by the NYSPSC. The debt of the Utilities is to be raised directly by the Utilities and not derived from Con Edison. Without the prior permission of the NYSPSC, the Utilities may not make loans to, guarantee the obligations of, or pledge assets as security for the indebtedness of Con Edison or its other subsidiaries. The NYSPSC limits the dividends that the Utilities may pay Con Edison. See “Dividends” in Note C. As a result, substantially all of the net assets of CECONY and O&R ($16,312 million and $888 million, respectively), at December 31, 2021, are considered restricted net assets. The NYSPSC may impose additional measures to separate, or “ring fence,” the Utilities from Con Edison and its other subsidiaries. See “Rate Plans” in Note B. The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2021, 2020 and 2019 were as follows: CECONY (Millions of Dollars) 2021 2020 2019 Cost of services provided $137 $128 $121 Cost of services received 68 66 64 In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $90 million, $59 million and $71 million of natural gas for the years ended December 31, 2021, 2020 and 2019, respectively. These amounts are net of the effect of related hedging transactions. The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest. The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the years ended December 31, 2021 and 2020, the amounts billed by the Utilities to NY Transco were $5.9 million and immaterial, respectively. In May 2016, CECONY transferred certain electric transmission projects to NY Transco. CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formerly owned by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. CECONY incurred costs for storage and wheeling services from Stagecoach of $31 million, $34 million and $33 million for the years ended December 31, 2021, 2020 and 2019, respectively. During 2021, a subsidiary of CET Gas completed the sale of its 50 percent interest in Stagecoach. See Note W. CECONY has a 20-year transportation contract with Mountain Valley Pipeline, LLC (MVP) for 250,000 dekatherms per day of capacity. CET Gas owns a 10.2 percent equity interest in MVP (that is expected to be reduced to 8.5 percent). See "Investments - 2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP) " in Note A. In October 2017, the Environmental Defense Fund and the Natural Resource Defense Council requested the NYSPSC to prohibit CECONY from recovering costs under its MVP contract unless CECONY can demonstrate that the contract is in the public interest. CECONY advised the NYSPSC that it would respond to the request if the NYSPSC opened a proceeding to consider this request. For the years ended December 31, 2021 and 2020, CECONY incurred no costs under the contract. FERC has authorized CECONY to lend funds to O&R for a period of not more than 12 months, in an amount not to exceed $250 million, at prevailing market rates. At December 31, 2021 and 2020 there were no outstanding loans to O&R. The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R during 2021 and 2020. For the years ended December 31, 2021 and 2020, the Clean Energy Businesses realized a $4 million loss and an immaterial loss, respectively, under these contracts.

New Financial Accounting Standa

New Financial Accounting Standards	12 Months Ended
	Dec. 31, 2021
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting StandardsIn March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. In March 2021, the United Kingdom's Financial Conduct Authority confirmed that U.S. Dollar LIBOR will no longer be published after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2022. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations or liquidity. In December 2021, the FASB issued amendments to the guidance on accounting for government assistance through ASU 2021-10, Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance. The amendments require that business entities disclose 1) the types of assistance, 2) an entity’s accounting for the assistance, and 3) the effect of the assistance on an entity’s financial statements. For public entities, the amendments are effective for reporting periods beginning after December 15, 2021. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2021
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions Crane and Coram In April 2021, a subsidiary of the Clean Energy Businesses entered into an agreement to sell substantially all of its membership interests in a renewable electric project that it developed and also all of its membership interests in a renewable electric project that it acquired in 2016. The sales were completed in June 2021. The combined carrying value of both projects was approximately $192 million in June 2021. The net pre-tax gain on the sales was $3 million ($2 million after-tax) and was included within "Other operations and maintenance" on Con Edison's consolidated income statement for the year ended December 31, 2021. The retained portion of the membership interest in the renewable electric project, of $11 million, was calculated based on a discounted cash flow of future projected earnings, and the retained portion is accounted for as an equity method investment. The portion of the gain attributable to the retained portion of the membership interest was not material for the year ended December 31, 2021. See Note S. Stagecoach Gas Services In 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET Gas) and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million, including closing adjustments, was attributed to CET Gas for its 50 percent interest. The purchase and sale agreement provided for a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. See "Investments - Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach)" in Note A.

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information	12 Months Ended
	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information	Schedule I Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Income and Comprehensive Income (Parent Company Only) For the Years Ended December 31, (Millions of Dollars, except per share amounts) 2021 2020 2019 Equity in earnings of subsidiaries $1,369 $1,105 $1,354 Other income (deductions), net of taxes 14 56 76 Interest expense (37) (60) (87) Net Income $1,346 $1,101 $1,343 Comprehensive Income $1,376 $1,095 $1,340 Net Income Per Share – Basic $3.86 $3.29 $4.09 Net Income Per Share – Diluted $3.85 $3.28 $4.08 Dividends Declared Per Share $3.10 $3.06 $2.96 Average Number Of Shares Outstanding—Basic (In Millions) 348.4 334.8 328.5 Average Number Of Shares Outstanding—Diluted (In Millions) 349.4 335.7 329.5 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Cash Flows (Parent Company Only) For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Net Income $1,346 $1,101 $1,343 Equity in earnings of subsidiaries (1,369) (1,105) (1,354) Dividends received from: CECONY 988 982 912 O&R 52 49 47 Clean Energy Businesses 64 21 3 Con Edison Transmission 152 11 12 Change in Assets: Special deposits — — (3) Income taxes receivable 15 — 25 Other – net (b) 211 (521) 44 Net Cash Flows from Operating Activities (b) 1,459 538 1,029 Investing Activities Contributions to subsidiaries (1,135) (626) (930) Debt receivable from affiliated companies 875 400 450 Net Cash Flows Used in Investing Activities (260) (226) (480) Financing Activities Net proceeds of short-term debt 50 (537) (783) Issuance of long-term debt — 650 825 Retirement of long-term debt (b) (1,178) (3) (553) Debt issuance costs (1) (3) — Issuance of common shares for stock plans, net of repurchases 60 58 54 Issuance of common shares - public offering 775 640 825 Common stock dividends (1,030) (975) (924) Net Cash Flows Used in Financing Activities (b) (1,324) (170) (556) Net Change for the Period (125) 142 (7) Balance at Beginning of Period 144 2 9 Balance at End of Period $19 $144 $2 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. (b) During 2021, Con Edison identified that the reclassification of debt from long-term to current for the year ended December 31, 2020 had been erroneously presented within the operating cash flow section as a cash inflow and in the financing section as a cash outflow in the Condensed Statement of Cash Flows (Parent Company Only). The amounts for the year ended December 31, 2020 have been revised to correct the error in the classification of $1,175 million from Other - net within Net Cash Flows from Operating Activities to Retirement of long-term debt within Net Cash Flows Used in Financing Activities. Con Edison has evaluated the effect of these misstatements, both qualitatively and quantitatively, and concluded that they are not material to the financial statements issued for the year ended December 31, 2020. These amounts were correctly presented on the Consolidated Statement of Cash Flows for the year ended December 31, 2020. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Balance Sheet (Parent Company Only) December 31, (Millions of Dollars) 2021 2020 Assets Current Assets Cash and temporary cash investments $19 $144 Accounts receivable - other — 1 Income taxes receivable 3 18 Accounts receivable from affiliated companies 1,199 1,256 Prepayments 28 62 Other current assets 14 12 Total Current Assets 1,263 1,493 Investments in subsidiaries and others 19,951 18,670 Goodwill 406 406 Deferred income tax — 55 Long-term debt receivable from affiliated companies — 875 Total Assets $21,620 $21,499 Liabilities and Shareholders’ Equity Current Liabilities Long-term debt due within one year $293 $1,178 Notes payable 50 — Accounts payable 1 — Accounts payable to affiliated companies 517 517 Accrued taxes 2 6 Other current liabilities 9 12 Total Current Liabilities 872 1,713 Deferred income tax 64 — Total Liabilities 936 1,713 Long-term debt 647 939 Shareholders’ Equity Common stock, including additional paid-in capital 9,748 8,844 Retained earnings 10,289 10,003 Total Shareholders’ Equity 20,037 18,847 Total Liabilities and Shareholders’ Equity $21,620 $21,499 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2021
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Schedule II Valuation and Qualifying Accounts For the Years Ended December 31, 2021, 2020 and 2019 COLUMN C Additions Company (Millions of Dollars) COLUMN A Description COLUMN B Balance at Beginning of Period (1) Charged To Costs And Expenses (2) Charged To Other Accounts COLUMN D Deductions (b) COLUMN E Balance At End of Period Con Edison Allowance for uncollectible accounts (a): 2021 $154 $83 $— $102 $339 2020 $74 $72 $— $8 $154 2019 $68 $77 $— $(71) $74 CECONY Allowance for uncollectible accounts (a): 2021 $143 $78 $— $102 $323 2020 $68 $65 $— $10 $143 2019 $61 $72 $— $(65) $68 (a) This is a valuation account deducted in the balance sheet from the assets (Accounts receivable - customers and Other receivables) to which they apply. (b) Accounts written off less cash collections, miscellaneous adjustments and amounts reinstated as receivables previously written off.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies and Other Matters (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note S), as required. All intercompany balances and intercompany transactions have been eliminated.
Accounting Policies	Accounting Policies The accounting policies of Con Edison and its subsidiaries conform to generally accepted accounting principles in the United States of America (GAAP). For the Utilities, these accounting principles include the accounting rules for regulated operations and the accounting requirements of the Federal Energy Regulatory Commission (FERC) and the state regulators having jurisdiction. The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations. The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2021 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.
Revenues	Revenues CECONY’s electric and gas rate plans and O&R’s NY electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B.
Plant and Depreciation Utility Plant	Plant and Depreciation Utility Plant Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (AFUDC). The original cost of property is charged to expense over the estimated useful lives of the assets. Upon retirement, the original cost of property is charged to accumulated depreciation. See Note T. Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 4.5 percent, 5.2 percent and 5.1 percent for 2021, 2020 and 2019, respectively. The AFUDC rates for O&R were 4.8 percent, 5.3 percent and 5.3 percent for 2021, 2020 and 2019, respectively. The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.5 percent for 2021 and 3.5 percent for 2020 and 3.2 percent for 2019. The average depreciation rates for O&R were 3.1 percent for 2021, 3.2 percent for 2020 and 3.0 percent for 2019. The estimated lives for utility plant for CECONY range from 5 to 85 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant. Non–Utility Plant Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on non-utility plant, other than land, is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years. Other Deferred Charges and Noncurrent Assets and Prepayments Other deferred charges and noncurrent assets and prepayments, net of accumulated depreciation, included the following related to implementation costs incurred in cloud computing arrangements: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Prepayments (a)(b) $16 $12 $15 $11 Other Deferred Charges and Noncurrent Assets (a)(b) $81 $54 $78 $51 (a) Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Depreciation expense related to these assets incurred during the year ended December 31, 2021 for Con Edison and CECONY was $12 million and $11 million, respectively, and for the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $22 million and $19 million, respectively at December 31, 2021 and was $10 million and $8 million, respectively at December 31, 2020.
Long-Lived and Intangible Assets	Long–Lived and Intangible Assets The Companies test long-lived and intangible assets for recoverability when events or changes in circumstances indicate that the carrying value of long-lived or intangible assets may not be recoverable. The carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value.
Recoverable Energy Costs/New York Independent System Operator (NYISO)	Recoverable Energy Costs The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month, the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs and costs of its electric demand management programs are generally deferred for charge or refund to customers during the next billing cycle (normally within one New York Independent System Operator (NYISO) The Utilities purchase electricity through the wholesale electricity market administered by the NYISO. The difference between purchased power and related costs initially billed to the Utilities by the NYISO and the actual cost of power subsequently calculated by the NYISO is refunded by the NYISO to the Utilities, or paid to the NYISO by the Utilities. The reconciliation payments or receipts are recoverable from or refundable to the Utilities’ customers. Certain other payments to or receipts from the NYISO are also subject to reconciliation, with shortfalls or amounts in excess of specified rate allowances recoverable from or refundable to customers. These include proceeds from the sale through the NYISO of transmission rights on CECONY’s transmission system (transmission congestion contracts or TCCs).
Temporary Cash Investments	Temporary Cash Investments Temporary cash investments are short-term, highly-liquid investments that generally have maturities of three months or less at the date of purchase. They are stated at cost, which approximates market. The Companies consider temporary cash investments to be cash equivalents.
Investments	Investments Accounting for Investments Con Edison’s investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities’ supplemental retirement income plan and deferred income plan assets. The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a market valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any. The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above. Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach) In 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET Gas) and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $629 million, including closing adjustments, was attributed to CET Gas for its 50 percent interest. The purchase and sale agreement provided for a two-stage closing, the first of which was completed in July 2021 and the second of which was completed in November 2021. As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the year ended December 31, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest in Stagecoach of $212 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the year ended December 31, 2021. Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 reflected the final sales price received in July 2021 and the remaining amount received in November 2021, including closing adjustments. 2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed 300-mile gas transmission project (the Project) in West Virginia and Virginia. During 2019, Con Edison exercised its right to limit, and did limit, its cash contributions to the joint venture to approximately $530 million, which reduced CET Gas' interest in MVP to 11.3 percent and 10.2 percent as of December 31, 2020 and 2021, respectively. CET Gas' interest in MVP is expected to be reduced to 8.5 percent based on the Project's current cost estimate and CET Gas' previous capping of its cash contributions. As of December 31, 2020 and 2021, the Project was approximately 92 percent and 94 percent complete, respectively. During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in a portion of the Project in West Virginia, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this certificate amendment would have led to additional Project costs and would have extended the anticipated in-service date. In January 2021, the FERC did not approve the requested certificate amendment. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a new certificate amendment application to the FERC to bore under other water crossings that, in total, would cover the entire Project length. The uncertainty related to obtaining necessary water crossing permits, the resulting Project costs and the likelihood of the Project not reaching eventual completion increased as a result of actions taken by the U.S. Court of Appeals for the Fourth Circuit. This action and associated delays constituted a triggering event (the "2020 triggering event") that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. In December 2021, the Virginia Department of Environmental Quality and the West Virginia Department of Environmental Protection both issued water quality certification permits which are required in order for the U.S. Army Corps of Engineers to proceed with the permitting process for construction of certain Project water crossings. In January 2022, the U.S. Court of Appeals for the Fourth Circuit rejected permits for crossings through the Jefferson National Forest issued by the U.S. Forest Service and Bureau of Land Management. In February 2022, the U.S. Court of Appeals for the Fourth Circuit vacated a biological opinion from the U.S. Fish and Wildlife Service, applicable to all remaining construction. The biological opinion had been issued and was the subject of litigation prior to December 31, 2021. Con Edison believes that the February 2022 action by the U.S. Court of Appeals for the Fourth Circuit, along with the potential outcome of other matters pending before that Court, may lead to further delays and increased Project costs, which constituted a triggering event (the “2021 triggering event”) that required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2021. In response to the 2020 triggering event and 2021 triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis as of December 31, 2020 and 2021, respectively. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note U. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. For the 2020 triggering event, Con Edison estimated that the likelihood of Project completion was in the upper end of a reasonably possible range. For the 2021 triggering event, Con Edison anticipated that the Project faces legal and regulatory challenges that make construction completion increasingly remote. The Project faces additional delays and increased costs that could further reduce CET Gas' interest in MVP to below 8 percent based on CET Gas' previous capping of its cash contributions. The likelihood that the Project will be completed and, for 2020, the discount rate, are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation. Based on the discounted cash flow analyses, Con Edison concluded as of December 31, 2020 and 2021 that the fair value of its investment in MVP declined below its carrying value and the declines were other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million, with an associated deferred tax asset of $53 million. Additionally, Con Edison recorded a pre-tax impairment loss of $231 million ($162 million, after tax) for the year ended December 31, 2021 that reduced the carrying value of its investment in MVP from $342 million to $111 million, with an additional $77 million associated deferred tax asset, totaling a deferred tax asset of $130 million at December 31, 2021. The impairments were recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison did not record non-cash equity in earnings from allowance for funds used during construction from MVP beginning in January 2021 and will continue to refrain from recording such amounts until such time as substantial construction activities resume, which would be indicative of probable Project completion. There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP.
Pension and Other Postretirement Benefits	Pension and Other Postretirement Benefits The accounting rules for retirement benefits require an employer to recognize an asset or liability for the overfunded or underfunded status of its pension and other postretirement benefit plans. For a pension plan, the asset or liability is the difference between the fair value of the plan’s assets and the projected benefit obligation. For any other postretirement benefit plan, the asset or liability is the difference between the fair value of the plan’s assets and the accumulated postretirement benefit obligation. The accounting rules generally require employers to recognize all unrecognized prior service costs and credits and unrecognized actuarial gains and losses in accumulated other comprehensive income/(loss) (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of total periodic benefit cost or income pursuant to the current recognition and amortization provisions. For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. Unrecognized prior service costs or credits and unrecognized actuarial gains and losses are recorded to regulatory assets or liabilities, rather than OCI. See Notes E and F. The total periodic benefit costs are recognized in accordance with the accounting rules for retirement benefits. Investment gains and losses are recognized in expense over a 15-year period and other actuarial gains and losses are recognized in expense over a 10-year period, subject to the deferral provisions in the rate plans. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between such expenses and the amounts for such expenses reflected in rates. O&R also defers such difference pursuant to its NY rate plans. See Note B. The Companies calculate the expected return on pension and other postretirement benefit plan assets by multiplying the expected rate of return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. The accounting rules allow the MRV of plan assets to be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. The Companies use a calculated value when determining the MRV of the plan assets that adjusts for 20 percent of the difference between fair value and expected MRV of plan assets. This calculated value has the effect of stabilizing variability in assets to which the Companies apply the expected return.
Federal Income Tax/State Income Tax	Federal Income Tax In accordance with accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability at current tax rates for temporary differences between the book and tax basis of assets and liabilities. In accordance with rate plans, the Utilities have recovered amounts from customers for a portion of the tax liability they will pay in the future as a result of the reversal or “turn-around” of these temporary differences. As to the remaining deferred tax liability, the Utilities had established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense pursuant to the NYSPSC's 1993 Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense. Con Edison and its subsidiaries file a consolidated federal income tax return. The consolidated income tax liability is allocated to each member of the consolidated group using the separate return method. Each member pays or receives an amount based on its own taxable income or loss in accordance with a consolidated tax allocation agreement. Tax loss and tax credit carryforwards are allocated among members in accordance with consolidated tax return regulations. State Income Tax Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member’s share of the New York State tax is based on its own New York State taxable income or loss.
Research and Development Costs	Research and Development CostsResearch and development costs are charged to operating expenses as incurred.
Reclassification	Reclassification Certain prior year amounts have been reclassified to conform with current year presentation.
Earnings Per Common Share	Earnings Per Common Share Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.
Estimates	Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
New Financial Accounting Standards	New Financial Accounting StandardsIn March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. In March 2021, the United Kingdom's Financial Conduct Authority confirmed that U.S. Dollar LIBOR will no longer be published after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2022. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations or liquidity. In December 2021, the FASB issued amendments to the guidance on accounting for government assistance through ASU 2021-10, Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance. The amendments require that business entities disclose 1) the types of assistance, 2) an entity’s accounting for the assistance, and 3) the effect of the assistance on an entity’s financial statements. For public entities, the amendments are effective for reporting periods beginning after December 15, 2021. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies and Other Matters (Tables)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Schedule of Total Excise Taxes Recorded in Operating Revenues	Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $358 $335 $323 CECONY 346 323 312
Capitalized Cost of Utility Plant	At December 31, 2021 and 2020, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Electric Generation $559 $572 $559 $572 Transmission 3,955 3,786 3,658 3,496 Distribution 22,418 21,481 21,240 20,366 General 87 52 87 52 Gas (a) 10,473 9,206 9,748 8,522 Steam 1,924 1,854 1,924 1,854 General 2,566 2,507 2,338 2,286 Held for future use 80 92 72 84 Construction work in progress 2,152 2,474 1,985 2,320 Net Utility Plant $44,214 $42,024 $41,611 $39,552 (a) Primarily distribution.
Schedule of Other Deferred Charges and Noncurrent Assets and Prepayments	Other deferred charges and noncurrent assets and prepayments, net of accumulated depreciation, included the following related to implementation costs incurred in cloud computing arrangements: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Prepayments (a)(b) $16 $12 $15 $11 Other Deferred Charges and Noncurrent Assets (a)(b) $81 $54 $78 $51 (a) Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. (b) Depreciation expense related to these assets incurred during the year ended December 31, 2021 for Con Edison and CECONY was $12 million and $11 million, respectively, and for the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $22 million and $19 million, respectively at December 31, 2021 and was $10 million and $8 million, respectively at December 31, 2020.
Schedule of Investment Assets	The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2021 and 2020: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 CET Gas investment in Stagecoach Gas Services LLC $— $845 $— $— CET Gas investment in Mountain Valley Pipeline, LLC (a) 111 342 — — Supplemental retirement income plan assets (b) 525 465 499 439 Deferred income plan assets 102 92 102 92 CET Electric investment in New York Transco, LLC (c) 112 69 — — Other 3 3 7 10 Total investments $853 $1,816 $608 $541 (a) At December 31, 2021 and 2020, CET Gas' cash investment in MVP was $530 million. In May 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is targeting an in-service date for the project of summer 2022 at an overall project cost of approximately $6,200 million excluding allowance for funds used during construction. See "2020 and 2021 Partial Impairments of Investment in Mountain Valley Pipeline, LLC (MVP)" above. (b) See Note E.
Research and Development Costs	Research and development costs were as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $25 $24 $24 CECONY 24 23 23
Basic and Diluted EPS	Basic and diluted EPS for Con Edison are calculated as follows: For the Years Ended December 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2021 2020 2019 Net income for common stock $1,346 $1,101 $1,343 Weighted average common shares outstanding – basic 348.4 334.8 328.5 Add: Incremental shares attributable to effect of potentially dilutive securities 1.0 0.9 1.0 Adjusted weighted average common shares outstanding – diluted 349.4 335.7 329.5 Net Income per common share – basic $3.86 $3.29 $4.09 Net Income per common share – diluted $3.85 $3.28 $4.08
Changes in Accumulated Other Comprehensive Income/(Loss)	Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: (Millions of Dollars) Con Edison CECONY Accumulated OCI, net of taxes, at December 31, 2018 (a) $(16) $(5) OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respectively (10) (3) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b) 7 2 Total OCI, net of taxes, at December 31, 2019 (3) (1) Accumulated OCI, net of taxes, at December 31, 2019 (a) $(19) $(6) OCI before reclassifications, net of tax of $4 and $1 for Con Edison and CECONY, respectively (11) (3) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b) 5 2 Total OCI, net of taxes, at December 31, 2020 (6) (1) Accumulated OCI, net of taxes, at December 31, 2020 (a) $(25) $(7) OCI before reclassifications, net of tax of $(8) and $(2) for Con Edison and CECONY, respectively 22 5 Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) and $(1) for Con Edison and CECONY, respectively (a)(b) 8 2 Total OCI, net of taxes, at December 31, 2021 30 7 Accumulated OCI, net of taxes, at December 31, 2021 (a) $5 $— (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement. (b) For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets and liabilities instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F.
Restrictions on Cash and Cash Equivalents	At December 31, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Cash and temporary cash investments $992 $1,272 $920 $1,067 Restricted cash (a) 154 164 — — Total cash, temporary cash investments and restricted cash $1,146 $1,436 $920 $1,067 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric project subsidiaries ($154 million and $164 million at December 31, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenditures, debt service, and required reserves until the various maturity dates of the project debt.
Schedule of Cash and Cash Equivalents	At December 31, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Cash and temporary cash investments $992 $1,272 $920 $1,067 Restricted cash (a) 154 164 — — Total cash, temporary cash investments and restricted cash $1,146 $1,436 $920 $1,067 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric project subsidiaries ($154 million and $164 million at December 31, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenditures, debt service, and required reserves until the various maturity dates of the project debt.

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Summary of Utilities Rate Plans	The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) Other revenue sources Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020 and 2021, the company recorded $34 million and $64 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020 and 2021, the company deferred for recovery from customers $242 million and $226 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased power and fuel costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020 and $3.2 million as a regulatory liability in 2021. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) (j) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Yr. 2 – 8.03 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (e) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr 1 - 10.0 basis points; Yr 2 - 7.5 basis points; and Yr 3 - 5.0 basis points. (f) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (h) Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (i) Calculated in accordance with the earnings calculation method prescribed in the rate order. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. In January 2022, CECONY filed a request with the NYSPSC for an electric rate increase of $1,199 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $853 million and $608 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) Other revenue sources Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020 and 2021, the company recorded $3 million and $26 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020 and 2021, the company recorded positive incentives of $13 million and $7 million, respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020 and 2021, the company deferred for recovery from customers $27 million and $100 million of revenues, respectively. Recoverable energy costs Continuation of current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. Cost reconciliations Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020 and 2021, the company deferred $24.7 million and $26 million as a regulatory liability, respectively. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent Yr. 1 to Yr. 3 – 6.61 percent Authorized return on common equity 9.0 percent 8.8 percent Actual return on common equity (i) (j) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Yr. 2 – 8.48 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020 and 2021, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent Yr. 1 to Yr. 3 – 4.63 percent Common equity ratio 48 percent 48 percent (a) In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (d) Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. (j) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. In January 2022, CECONY filed a request with the NYSPSC for a gas rate increase of $503 million, effective January 2023. The filing reflects a return on common equity of 10.0 percent and a common equity ratio of 50 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates and a reconciliation of the impacts of inflation on operation and maintenance expenses under certain circumstances. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filed gas revenue requirement includes additional depreciation expense of $48 million. Included in this increase is the impact of the company’s proposal to decrease the service lives for the longer-lived gas accounts by five years. The filing includes supplemental information regarding gas rate plans for 2024 and 2025, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $234 million and $218 million effective January 2024 and 2025, respectively, were calculated based upon an assumed return on common equity of 10.0 percent and a common equity ratio of 50 percent. CECONY – Steam Effective period January 2014 – December 2016 (a) Base rate changes Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Amortizations to income of net $37 million over three years Recoverable energy costs Current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2021, the company did not record any negative revenue adjustments. Cost reconciliations (c)(d) In 2014, 2015, 2016, 2017, 2018, 2019, 2020 and 2021, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets and $32 million of net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020 and by $0.6 million in 2021. Average rate base Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent Authorized return on common equity 9.3 percent Actual return on common equity (e) Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Earnings sharing Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020 and 2021, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent Common equity ratio 48 percent (a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC. (b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. (d) In addition, the NYSPSC staff has commenced a focused operations audit to investigate CECONY’s income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. CECONY’s historical inadvertent understatement of its calculation of total federal income tax expense for ratemaking purposes has not been addressed in the current steam rate plan. See "Other Regulatory Matters," below. (e) Calculated in accordance with the earnings calculation method prescribed in the rate order. In October 2021, O&R, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for new electric and gas rate plans for the three-year period January 2022 through December 2024 (the Joint Proposal). The Joint Proposal is subject to NYSPSC approval. The Joint Proposal includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ( $2.8 million ); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. The following tables contain a summary of the current and proposed rate plans. O&R New York – Electric Effective period (a) January 2019 – December 2021 January 2022 – December 2024 Base rate changes Yr. 1 – $13.4 million (b) Yr. 2 – $8.0 million (b) Yr. 3 – $5.8 million (b) Yr. 1 – $4.9 million (i) Yr. 2 – $16.2 million (i) Yr. 3 – $23.1 million (i) Amortizations to income of net Yr. 1 – $(1.5) million (c) Yr. 2 – $(1.5) million (c) Yr. 3 – $(1.5) million (c) Yr. 1 – $11.8 million (j) Yr. 2 – $13.5 million (j) Yr. 3 – $15.2 million (j) Other revenue sources Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $10 million was deferred as regulatory liabilities. Continuation of reconciliation of actual to authorized electric delivery revenues. Recoverable energy costs Continuation of current rate recovery of purchased power costs. Continuation of current rate recovery of purchased power and fuel costs. Negative revenue adjustments Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019,2020 and 2021, the company did not record any negative revenue adjustments. Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $4.3 million Yr. 2 – $4.4 million Yr. 3 – $5.1 million Cost reconciliations Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (e), major storms, the impact of new laws and certain other costs to amounts reflected in rates (f). In 2019, 2020 and 2021, the company deferred $4.3 million, $30.3 million and $24 million as net regulatory assets, respectively. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (k), major storms, and certain other costs to amounts reflected in rates. Net utility plant reconciliations Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (g): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019, $0.4 million as a regulatory liability in 2020 and an immaterial amount as a regulatory liability in 2021. Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,175 million Yr. 2 – $1,198 million Yr. 3 – $1,304 million Average rate base Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million Weighted average cost of capital (after-tax) Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent Authorized return on common equity 9.0 percent 9.2 percent Actual return on common equity (h) Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Yr. 3 – 9.16 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019, 2020 and 2021, earnings did not exceed the earnings threshold. Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. Cost of long-term debt Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent Common equity ratio 48 percent 48 percent (a) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note U ) are not necessary. (b) The electric base rate increases were implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (c) Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below. (d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact o
Schedule of Regulatory Assets	Regulatory assets and liabilities at December 31, 2021 and 2020 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Regulatory assets Unrecognized pension and other postretirement costs $128 $3,241 $110 $3,065 Environmental remediation costs 938 865 860 791 Pension and other postretirement benefits deferrals 496 315 435 272 Revenue taxes 395 356 378 342 System peak reduction and energy efficiency programs 285 124 284 124 COVID - 19 Deferrals 282 115 277 113 Deferred storm costs 276 195 158 83 Property tax reconciliation 202 241 202 239 MTA power reliability deferral 140 188 140 188 Deferred derivative losses 51 120 45 111 Municipal infrastructure support costs 44 62 44 62 Brooklyn Queens demand management program 36 36 36 36 Meadowlands heater odorization project 29 32 29 32 Non-wire alternative projects 23 18 23 18 Preferred stock redemption 20 21 20 21 Unamortized loss on reacquired debt 16 21 14 19 Recoverable REV demonstration project costs 16 20 15 18 Gate station upgrade project 14 25 14 25 Other 248 200 232 186 Regulatory assets – noncurrent 3,639 6,195 3,316 5,745 Deferred derivative losses 141 190 133 177 Recoverable energy costs 65 76 55 67 Regulatory assets – current 206 266 188 244 Total Regulatory Assets $3,845 $6,461 $3,504 $5,989 Regulatory liabilities Future income tax* $1,984 $2,207 $1,840 $2,062 Allowance for cost of removal less salvage 1,199 1,090 1,033 932 Net unbilled revenue deferrals 209 198 209 198 TCJA net benefits 125 295 123 286 Net proceeds from sale of property 103 137 103 137 Pension and other postretirement benefit deferrals 102 85 55 46 System benefit charge carrying charge 70 64 63 57 Deferred derivative gains - long term 61 5 55 4 Property tax refunds 35 36 35 35 Unrecognized other postretirement costs 32 11 — — BQDM and REV Demo reconciliations 25 27 22 25 Sales and use tax refunds 17 16 16 16 Energy efficiency portfolio standard unencumbered funds 15 1 19 — Earnings sharing - electric, gas and steam 13 15 10 10 Settlement of gas proceedings 12 21 12 21 Workers’ compensation 8 3 8 3 Settlement of prudence proceeding 6 5 6 5 Other 365 297 312 257 Regulatory liabilities – noncurrent 4,381 4,513 3,921 4,094 Refundable energy costs 32 28 2 4 Deferred derivative gains 142 8 132 7 Revenue decoupling mechanism 11 — — — Regulatory liabilities—current 185 36 134 11 Total Regulatory Liabilities $4,566 $4,549 $4,055 $4,105 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities at December 31, 2021 and 2020 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Regulatory assets Unrecognized pension and other postretirement costs $128 $3,241 $110 $3,065 Environmental remediation costs 938 865 860 791 Pension and other postretirement benefits deferrals 496 315 435 272 Revenue taxes 395 356 378 342 System peak reduction and energy efficiency programs 285 124 284 124 COVID - 19 Deferrals 282 115 277 113 Deferred storm costs 276 195 158 83 Property tax reconciliation 202 241 202 239 MTA power reliability deferral 140 188 140 188 Deferred derivative losses 51 120 45 111 Municipal infrastructure support costs 44 62 44 62 Brooklyn Queens demand management program 36 36 36 36 Meadowlands heater odorization project 29 32 29 32 Non-wire alternative projects 23 18 23 18 Preferred stock redemption 20 21 20 21 Unamortized loss on reacquired debt 16 21 14 19 Recoverable REV demonstration project costs 16 20 15 18 Gate station upgrade project 14 25 14 25 Other 248 200 232 186 Regulatory assets – noncurrent 3,639 6,195 3,316 5,745 Deferred derivative losses 141 190 133 177 Recoverable energy costs 65 76 55 67 Regulatory assets – current 206 266 188 244 Total Regulatory Assets $3,845 $6,461 $3,504 $5,989 Regulatory liabilities Future income tax* $1,984 $2,207 $1,840 $2,062 Allowance for cost of removal less salvage 1,199 1,090 1,033 932 Net unbilled revenue deferrals 209 198 209 198 TCJA net benefits 125 295 123 286 Net proceeds from sale of property 103 137 103 137 Pension and other postretirement benefit deferrals 102 85 55 46 System benefit charge carrying charge 70 64 63 57 Deferred derivative gains - long term 61 5 55 4 Property tax refunds 35 36 35 35 Unrecognized other postretirement costs 32 11 — — BQDM and REV Demo reconciliations 25 27 22 25 Sales and use tax refunds 17 16 16 16 Energy efficiency portfolio standard unencumbered funds 15 1 19 — Earnings sharing - electric, gas and steam 13 15 10 10 Settlement of gas proceedings 12 21 12 21 Workers’ compensation 8 3 8 3 Settlement of prudence proceeding 6 5 6 5 Other 365 297 312 257 Regulatory liabilities – noncurrent 4,381 4,513 3,921 4,094 Refundable energy costs 32 28 2 4 Deferred derivative gains 142 8 132 7 Revenue decoupling mechanism 11 — — — Regulatory liabilities—current 185 36 134 11 Total Regulatory Liabilities $4,566 $4,549 $4,055 $4,105 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule of Regulatory Assets Not Earning Return	At December 31, 2021 and 2020, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items: Regulatory Assets Not Earning a Return* Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Unrecognized pension and other postretirement costs $128 $3,241 $110 $3,065 Environmental remediation costs 928 855 850 781 Revenue taxes 375 336 359 323 Deferred derivative losses - long term 51 120 45 111 COVID-19 Deferral for Uncollectible Accounts Receivable 236 57 231 55 Other 24 24 24 24 Deferred derivative losses - current 141 190 134 177 Total $1,883 $4,823 $1,753 $4,536

Capitalization (Tables)

Capitalization (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Maturities	Long-term debt maturing in the period 2022-2026 is as follows: (Millions of Dollars) Con Edison CECONY 2022 $440 $— 2023 969 — 2024 393 250 2025 319 — 2026 385 250
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at December 31, 2021 and 2020 are: (Millions of Dollars) 2021 2020 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $23,044 $26,287 $22,349 $26,808 CECONY $18,382 $21,382 $16,789 $20,974 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $226 million and $193 million for Con Edison and CECONY, respectively, as of December 31, 2021 and $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020.

Pension Benefits (Tables)

Pension Benefits (Tables)	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost – including administrative expenses $343 $293 $250 $321 $274 $232 Interest cost on projected benefit obligation 471 549 601 443 515 564 Expected return on plan assets (1,096) (1,034) (988) (1,040) (980) (936) Recognition of net actuarial loss 787 699 518 746 661 492 Recognition of prior service credit (17) (16) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $488 $491 $364 $451 $451 $333 Cost capitalized (154) (130) (108) (146) (123) (102) Reconciliation to rate level (226) (250) (15) (216) (239) (12) Total expense recognized $108 $111 $241 $89 $89 $219 Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost $22 $21 $18 $16 $16 $13 Interest cost on accumulated other postretirement benefit obligation 33 37 44 28 31 36 Expected return on plan assets (68) (66) (66) (56) (54) (54) Recognition of net actuarial loss/(gain) 31 37 (9) 27 36 (10) Recognition of prior service credit (3) (3) (2) (1) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $15 $26 $(15) $14 $27 $(17) Cost capitalized (9) (9) (7) (7) (7) (5) Reconciliation to rate level (7) (17) 12 (12) (25) 7 Total credit recognized $(1) $— $(10) $(5) $(5) $(15)
Schedule of Funded Status	The funded status at December 31, 2021, 2020 and 2019 was as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 Service cost – excluding administrative expenses 337 288 245 317 269 228 Interest cost on projected benefit obligation 471 549 601 443 515 564 Net actuarial loss/(gain) (1,547) 2,281 2,191 (1,441) 2,154 2,076 Plan amendments — — 15 — — — Benefits paid (869) (945) (709) (799) (867) (660) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 Actual return on plan assets 1,935 1,927 2,556 1,838 1,830 2,425 Employer contributions 469 475 350 432 435 318 Benefits paid (869) (945) (709) (799) (867) (660) Administrative expenses (53) (43) (39) (52) (41) (37) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 FUNDED STATUS $1,147 $(1,943) $(1,184) $1,225 $(1,674) $(960) Unrecognized net loss $205 $3,330 $2,604 $207 $3,145 $2,466 Unrecognized prior service costs/(credits) (140) (156) (173) (163) (183) (202) Accumulated benefit obligation 15,469 16,768 15,015 14,504 15,676 14,010 The funded status of the programs at December 31, 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,425 $1,357 $1,114 $1,209 $1,154 $913 Service cost 22 21 18 16 16 13 Interest cost on accumulated postretirement benefit obligation 33 37 44 28 31 36 Amendments — — (14) — — — Net actuarial loss/(gain) (13) 74 264 (3) 63 252 Benefits paid and administrative expenses, net of subsidies (117) (117) (110) (107) (107) (100) Participant contributions 48 53 41 46 52 40 BENEFIT OBLIGATION AT END OF YEAR $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,115 $1,026 $885 $940 $872 $759 Actual return on plan assets 92 142 198 67 117 165 Employer contributions 6 7 7 3 4 6 Employer group waiver plan subsidies 21 20 23 19 19 22 Participant contributions 48 53 40 46 51 40 Benefits paid (132) (133) (127) (120) (123) (120) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,150 $1,115 $1,026 $955 $940 $872 FUNDED STATUS $(248) $(310) $(331) $(234) $(269) $(282) Unrecognized net loss/(gain) $41 $115 $155 $67 $114 $149 Unrecognized prior service costs (13) (16) (19) — (1) (3)
Schedule of Assumptions	The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Expected return on plan assets 7.00 % 7.00 % 7.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Expected Return on Plan Assets 6.80 % 6.80 % 6.80 %
Schedule of Expected Benefit Payments	Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $765 $782 $791 $841 $818 $4,219 CECONY 704 721 730 780 756 3,924 Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies and participant contributions: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $75 $77 $77 $78 $78 $385 CECONY 84 86 86 87 88 435
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 45% - 55% 50 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 38 % Real Estate 10% - 14% 12 % 11 % 11 % Total 100% 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 42%-80% 55 % 54 % 54 % Debt Securities 20%-58% 45 % 46 % 46 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists of global equity funds that are not exchange-traded. (j) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (k) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (l) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F. (m) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end. (n) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2021 by asset category. The fair values of the plans' assets at December 31, 2021 by asset category as defined by the accounting rules for fair value measurements (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note E. (e) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. (f) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year-end. The fair values of the plans' assets at December 31, 2020 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115
Schedule of Employer Contribution to Defined Savings Plan	The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Con Edison $55 $52 $49 CECONY 46 43 42

Other Postretirement Benefits (

Other Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Net Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost – including administrative expenses $343 $293 $250 $321 $274 $232 Interest cost on projected benefit obligation 471 549 601 443 515 564 Expected return on plan assets (1,096) (1,034) (988) (1,040) (980) (936) Recognition of net actuarial loss 787 699 518 746 661 492 Recognition of prior service credit (17) (16) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $488 $491 $364 $451 $451 $333 Cost capitalized (154) (130) (108) (146) (123) (102) Reconciliation to rate level (226) (250) (15) (216) (239) (12) Total expense recognized $108 $111 $241 $89 $89 $219 Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Service cost $22 $21 $18 $16 $16 $13 Interest cost on accumulated other postretirement benefit obligation 33 37 44 28 31 36 Expected return on plan assets (68) (66) (66) (56) (54) (54) Recognition of net actuarial loss/(gain) 31 37 (9) 27 36 (10) Recognition of prior service credit (3) (3) (2) (1) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $15 $26 $(15) $14 $27 $(17) Cost capitalized (9) (9) (7) (7) (7) (5) Reconciliation to rate level (7) (17) 12 (12) (25) 7 Total credit recognized $(1) $— $(10) $(5) $(5) $(15)
Schedule of Funded Status	The funded status at December 31, 2021, 2020 and 2019 was as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 Service cost – excluding administrative expenses 337 288 245 317 269 228 Interest cost on projected benefit obligation 471 549 601 443 515 564 Net actuarial loss/(gain) (1,547) 2,281 2,191 (1,441) 2,154 2,076 Plan amendments — — 15 — — — Benefits paid (869) (945) (709) (799) (867) (660) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $17,357 $18,965 $16,792 $16,341 $17,821 $15,750 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 Actual return on plan assets 1,935 1,927 2,556 1,838 1,830 2,425 Employer contributions 469 475 350 432 435 318 Benefits paid (869) (945) (709) (799) (867) (660) Administrative expenses (53) (43) (39) (52) (41) (37) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $18,504 $17,022 $15,608 $17,566 $16,147 $14,790 FUNDED STATUS $1,147 $(1,943) $(1,184) $1,225 $(1,674) $(960) Unrecognized net loss $205 $3,330 $2,604 $207 $3,145 $2,466 Unrecognized prior service costs/(credits) (140) (156) (173) (163) (183) (202) Accumulated benefit obligation 15,469 16,768 15,015 14,504 15,676 14,010 The funded status of the programs at December 31, 2021, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,425 $1,357 $1,114 $1,209 $1,154 $913 Service cost 22 21 18 16 16 13 Interest cost on accumulated postretirement benefit obligation 33 37 44 28 31 36 Amendments — — (14) — — — Net actuarial loss/(gain) (13) 74 264 (3) 63 252 Benefits paid and administrative expenses, net of subsidies (117) (117) (110) (107) (107) (100) Participant contributions 48 53 41 46 52 40 BENEFIT OBLIGATION AT END OF YEAR $1,398 $1,425 $1,357 $1,189 $1,209 $1,154 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,115 $1,026 $885 $940 $872 $759 Actual return on plan assets 92 142 198 67 117 165 Employer contributions 6 7 7 3 4 6 Employer group waiver plan subsidies 21 20 23 19 19 22 Participant contributions 48 53 40 46 51 40 Benefits paid (132) (133) (127) (120) (123) (120) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,150 $1,115 $1,026 $955 $940 $872 FUNDED STATUS $(248) $(310) $(331) $(234) $(269) $(282) Unrecognized net loss/(gain) $41 $115 $155 $67 $114 $149 Unrecognized prior service costs (13) (16) (19) — (1) (3)
Schedule of Actuarial Assumptions	The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 3.00 % 2.55 % 3.35 % Interest crediting rate for cash balance plan 3.50 % 3.00 % 3.30 % Rate of compensation increase CECONY 3.80 % 3.80 % 3.80 % O&R 3.20 % 3.20 % 3.20 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Expected return on plan assets 7.00 % 7.00 % 7.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % The actuarial assumptions were as follows: 2021 2020 2019 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.75 % 2.25 % 3.10 % O&R 3.00 % 2.55 % 3.35 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Expected Return on Plan Assets 6.80 % 6.80 % 6.80 %
Schedule of Health Care Cost Trend Rates	The health care cost trend rates for covered medical and prescription medication expenses used to determine the accumulated other postretirement benefit obligations (APBO) at December 31, 2021 were assumed to increase each year, with the initial rate gradually decreasing to the ultimate rate as follows: Initial Cost Trend Rate Ultimate Cost Trend Rate Year That Ultimate Rate is Reached Pre-65 Medical 6.80% 4.50% 2034 Post-65 Medical 4.50% 4.50% — Prescription Medications 7.25% 4.50% 2033
Schedule of Expected Benefit Payments	Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $765 $782 $791 $841 $818 $4,219 CECONY 704 721 730 780 756 3,924 Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies and participant contributions: (Millions of Dollars) 2022 2023 2024 2025 2026 2027-2031 Con Edison $75 $77 $77 $78 $78 $385 CECONY 84 86 86 87 88 435
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 45% - 55% 50 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 38 % Real Estate 10% - 14% 12 % 11 % 11 % Total 100% 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2021, 2020 and 2019, and the target allocation for 2022 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2022 2021 2020 2019 Equity Securities 42%-80% 55 % 54 % 54 % Debt Securities 20%-58% 45 % 46 % 46 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2021 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,381 $— $4,381 International Equity (b) 3,536 — 3,536 U.S. Government Issued Debt (c) 1,500 1,500 Corporate Bonds Debt (d) — 3,936 3,936 Structured Assets Debt (e) — 262 262 Other Fixed Income Debt (f) — 1,186 1,186 Cash and Cash Equivalents (g) 80 425 505 Futures (h) 2 — 2 Total investments within the fair value hierarchy $7,999 $7,309 $15,308 Investments measured at NAV per share (n) Private Equity (i) 913 Real Estate (j) 2,306 Hedge Funds (k) 315 Total investments valued using NAV per share $3,534 Funds for retiree health benefits (l) (110) (100) (210) Funds for retiree health benefits measured at NAV per share (l)(n) (48) Total funds for retiree health benefits $(258) Investments (excluding funds for retiree health benefits) $7,889 $7,209 $18,584 Pending activities (m) (80) Total fair value of plan net assets $18,504 (a) U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities. (b) International Equity includes international equity index funds and actively-managed international equities. (c) U.S. Government Issued Debt includes agency and treasury securities. (d) Corporate Bonds Debt consists of debt issued by various corporations. (e) Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations. (f) Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments. (g) Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral. (h) Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices. (i) Private Equity consists of global equity funds that are not exchange-traded. (j) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (k) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (l) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F. (m) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end. (n) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2021 by asset category. The fair values of the plans' assets at December 31, 2021 by asset category as defined by the accounting rules for fair value measurements (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $474 $474 Other Fixed Income Debt (b) — 379 379 Cash and Cash Equivalents (c) — 22 22 Total investments $— $875 $875 Funds for retiree health benefits (d) 110 100 210 Investments (including funds for retiree health benefits) $110 $975 $1,085 Funds for retiree health benefits measured at net asset value (d)(e) 48 Pending activities (f) 17 Total fair value of plan net assets $1,150 (a) Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index. (b) Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index. (c) Cash and Cash Equivalents include short-term investments and money markets. (d) The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note E. (e) In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. (f) Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year-end. The fair values of the plans' assets at December 31, 2020 by asset category (see Note R) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115

Environmental Matters (Tables)

Environmental Matters (Tables)	12 Months Ended
	Dec. 31, 2021
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Accrued Liabilities: Manufactured gas plant sites $845 $752 $755 $676 Other Superfund Sites 95 105 95 104 Total $940 $857 $850 $780 Regulatory assets $938 $865 $860 $791
Environmental Remediation Costs	Environmental remediation costs incurred related to Superfund Sites at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Remediation costs incurred $25 $33 $24 $32
Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings	The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets or liabilities for the Companies at December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $65 $72 $62 $68 Regulatory liabilities – workers’ compensation $8 $3 $8 $3

Material Contingencies (Tables)

Material Contingencies (Tables)	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Summary of Total Guarantees	A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2021 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $490 $— $— $490 Energy transactions 469 37 325 831 Renewable electric projects 319 51 396 766 Other 70 — — 70 Total $1,348 $88 $721 $2,157

Electricity Purchase Agreemen_2

Electricity Purchase Agreements (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Abstract]
Summary of Estimated Capacity and Other Fixed Payments	The future capacity and other fixed payments under the electricity purchase agreements are estimated to be as follows: (Millions of Dollars) 2022 2023 2024 2025 2026 All Years Thereafter Con Edison $126 $78 $55 $55 $56 $434 CECONY 124 78 55 55 56 434
Summary of Capacity, Energy and Other Fixed Payments	The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2021, 2020 and 2019 were as follows: For the Years Ended December 31, (Millions of Dollars) 2021 2020 2019 Astoria Generating Company (a) $20 $26 $116 Brooklyn Navy Yard (b) 139 113 115 Total $159 $139 $231 (a) Capacity purchase agreements with terms ending in 2021 through 2023. (b) Contract for plant output, which started in 1996 and ends in 2036.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Lease Costs, Cash Flows and Other Related Information	Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2021 and 2020 were as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Operating lease cost $86 $85 $66 $65 Operating lease cash flows $80 $79 $63 $61 Other information related to leases for Con Edison and CECONY at December 31, 2021 and 2020 was as follows: Con Edison CECONY 2021 2020 2021 2020 Weighted Average Remaining Lease Term: Operating leases 18.5 years 19.1 years 12.1 years 13.0 years Finance leases 7.1 years 7.3 years 3.1 years 4.0 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.5% 3.6% Finance leases 1.8% 1.8% 1.1% 1.3%
Operating Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2021 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2022 $81 $— $60 $— 2023 77 — 59 — 2024 77 1 59 1 2025 78 — 60 — 2026 76 — 59 — All years thereafter 877 1 394 — Total future minimum lease payments $1,266 $2 $691 $1 Less: imputed interest (436) — (139) — Total $830 $2 $552 $1 Reported as of December 31, 2021 Operating lease liabilities (current) $113 $— $90 $— Operating lease liabilities (noncurrent) 717 — 462 — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $830 $2 $552 $1
Finance Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2021 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2022 $81 $— $60 $— 2023 77 — 59 — 2024 77 1 59 1 2025 78 — 60 — 2026 76 — 59 — All years thereafter 877 1 394 — Total future minimum lease payments $1,266 $2 $691 $1 Less: imputed interest (436) — (139) — Total $830 $2 $552 $1 Reported as of December 31, 2021 Operating lease liabilities (current) $113 $— $90 $— Operating lease liabilities (noncurrent) 717 — 462 — Other current liabilities — — — — Other noncurrent liabilities — 2 — 1 Total $830 $2 $552 $1

Income Tax (Tables)

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax	The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 State Current $14 $7 $(12) $1 $6 $22 Deferred 79 50 96 106 97 68 Federal Current 43 (2) — 121 41 185 Deferred 61 42 219 21 73 63 Amortization of investment tax credits (7) (7) (7) (3) (2) (3) Total income tax expense $190 $90 $296 $246 $215 $335
Schedule of Differences on Deferred Tax Assets and Liabilities	The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 0 Deferred tax liabilities: Property basis differences $8,298 $7,985 $7,213 $6,901 Regulatory assets: Unrecognized pension and other postretirement costs 36 910 31 861 Environmental remediation costs 264 243 241 222 Deferred storm costs 33 31 — — Other regulatory assets 640 536 609 508 Operating lease right-of-use asset 204 220 155 165 Pension Asset Reserve 478 — 471 — Equity investments — 46 — — Other 30 — — — Total deferred tax liabilities $9,983 $9,971 $8,720 $8,657 Deferred tax assets: Accrued pension and other postretirement costs $218 $504 $188 $427 Regulatory liabilities: Future income tax 554 617 517 579 Other regulatory liabilities 727 656 620 570 Superfund and other environmental costs 264 241 238 219 Asset retirement obligations 177 178 141 143 Operating lease liabilities 195 211 155 165 Loss carryforwards 144 164 38 34 Tax credits carryforward 946 1,022 — — Valuation allowance (22) (22) — — Equity investments 34 — — — Other — 59 42 127 Total deferred tax assets 3,237 3,630 1,939 2,264 Net deferred tax liabilities $6,746 $6,341 $6,781 $6,393 Unamortized investment tax credits 127 134 15 18 Net deferred tax liabilities and unamortized investment tax credits $6,873 $6,475 $6,796 $6,411
Schedule of Income Tax Reconciliation	Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows: Con Edison CECONY (% of Pre-tax income) 2021 2020 2019 2021 2020 2019 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income taxes, net of federal income tax benefit 4 4 4 5 5 5 Taxes attributable to noncontrolling interests 3 (1) (1) — — — Cost of removal 2 2 1 1 1 1 Other plant-related items (1) (1) (1) (1) (1) (1) Amortization of excess deferred federal income taxes (12) (14) (4) (11) (12) (4) Renewable energy credits (2) (3) (2) — — — Research and development credits (1) — (1) — — (1) Other — (1) — — 1 — Effective tax rate 14 % 7 % 17 % 15 % 15 % 21 %
Summary of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Balance at January 1, $14 $13 $6 $3 $2 $4 Additions based on tax positions related to the current year 3 — 1 2 — 1 Additions based on tax positions of prior years 2 1 10 1 1 — Reductions for tax positions of prior years (2) — (2) (1) — (1) Reductions from expiration of statute of limitations — — — — — — Settlements — — (2) — — (2) Balance at December 31, $17 $14 $13 $5 $3 $2

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table presents, for the years ended December 31, 2021, 2020 and 2019, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. 2021 2020 2019 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $8,736 $70 $8,806 $8,026 $77 $8,103 $7,913 $149 $8,062 Gas 2,324 54 2,378 1,998 38 2,036 2,097 35 2,132 Steam 519 13 532 494 14 508 610 17 627 Total CECONY $11,579 $137 $11,716 $10,518 $129 $10,647 $10,620 $201 $10,821 O&R Electric 691 (10) 681 619 10 629 627 7 634 Gas 265 (5) 260 224 9 233 247 12 259 Total O&R $956 $(15) $941 $843 $19 $862 $874 $19 $893 Clean Energy Businesses Renewables 683 — 683 609 — 609 575 — 575 Energy services 234 — 234 52 — 52 71 — 71 Other — 105 105 — 75 75 — 211 211 Total Clean Energy Businesses $917 $105 $1,022 $661 $75 $736 $646 $211 $857 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (b) — (7) (7) — (3) (3) — (1) (1) Total Con Edison $13,456 $220 $13,676 $12,026 $220 $12,246 $12,144 $430 $12,574 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their NY electric and gas rate plans, as well as net earnings adjustment mechanisms (EAMs) and positive incentives primarily for achieving energy efficiency goals (see "Rate Plans" in Note B), and for 2021 recognition of late payment charges and fees that were not billed (LPCs) for the years ended December 31, 2020 and 2021 and for which recovery was granted by the NYSPSC. See "COVID-19 Regulatory Matters" in Note B and "Utilities' Assessment of Late Payment Charges" below. The amount of revenue recognized under such alternative revenue programs for 2021 includes $48 million, $34 million and $74 million for CECONY's revenue decoupling mechanisms, net EAMs, and LPCs, respectively, and $(18) million, $2 million and $4 million for O&R's revenue decoupling mechanisms, net EAMs, and LPCs, respectively. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Parent company and consolidation adjustments.
Change in Unbilled Contract and Unearned Revenues	2021 2020 2019 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $11 $41 $29 $17 $29 $20 Additions (c) 242 — 88 31 86 1 Subtractions (c) 218 34 (d) 106 7 (d) 86 4 (d) Ending balance as of December 31, $35 $7 $11 $41 $29 $17 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. (d) Of the subtractions from unearned revenue, $34 million, $7 million and $4 million were included in the balances as of January 1, 2021, 2020, and 2019, respectively.

Current Expected Credit Losses

Current Expected Credit Losses (Tables)	12 Months Ended
	Dec. 31, 2021
Credit Loss [Abstract]
Rollforward of Allowance for Credit Losses	The table below presents a rollforward by major portfolio segment type for the years ended December 31, 2021 and 2020: For the Year Ended December 31, Con Edison CECONY Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables (Millions of Dollars) 2021 2020 2021 2020 2021 2020 2021 2020 Allowance for credit losses Beginning Balance at January 1, $148 $70 $7 $4 $138 $65 $4 $3 Recoveries 14 8 1 — 12 6 1 — Write-offs (91) (54) (2) (2) (86) (50) (1) (1) Reserve adjustments 246 124 16 5 240 117 15 2 Ending Balance December 31, $317 $148 $22 $7 $304 $138 $19 $4

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Summary of Stock-Based Compensation Expense	The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2021, 2020 and 2019: Con Edison CECONY (Millions of Dollars) 2021 2020 2019 2021 2020 2019 Performance-based restricted stock $23 $7 $36 $19 $6 $30 Time-based restricted stock 2 1 2 2 1 2 Non-employee director deferred stock compensation 3 2 2 3 2 2 Stock purchase plan 7 7 7 7 7 6 Total $35 $17 $47 $31 $16 $40 Income tax benefit $10 $5 $13 $9 $4 $11
Assumptions Used to Calculate Fair Value of Awards	The assumptions used to calculate the fair value of the awards were as follows: 2021 2020 2019 Risk-free interest rate (a) 0.39% - 0.73% 0.10% - 0.13% 1.58% -1.59% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 17.25% - 31.42% 30.16% - 40.95% 12.89% - 15.51% (a) The risk-free rate is based on the U.S. Treasury zero-coupon yield curve. (b) The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur. (c) Based on historical experience. The Companies would reevaluate this assumption if market conditions or business developments would reasonably indicate that future volatility might differ materially from historical experience.
Summary of Changes in Status of Performance RSUs	A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2021 is as follows: Con Edison CECONY Weighted Average Grant Date Fair Value (a) Weighted Average Grant Date Fair Value (a) Units TSR Portion (b) Non-TSR Portion (c) Units TSR Portion (b) Non-TSR Portion (c) Non-vested at December 31, 2020 901,524 $70.11 $81.83 686,471 $70.15 $81.80 Granted 401,100 74.46 71.04 301,087 74.23 71.25 Vested (301,600) 67.27 76.37 (227,411) 66.82 76.48 Forfeited (16,296) 75.23 79.78 (15,869) 75.21 79.84 Non-vested at December 31, 2021 984,728 $72.67 $79.14 744,278 $72.71 $79.20 (a) The TSR and non-TSR Portions each account for 50 percent of the awards’ value. (b) Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting. (c) Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting.
Summary of Changes in Status of Time-Based Awards	A summary of changes in the status of time-based awards during the year ended December 31, 2021 is as follows: Con Edison CECONY Units Weighted Average Grant Date Fair Value Units Weighted Average Grant Date Fair Value Non-vested at December 31, 2020 67,438 $80.40 62,838 $80.42 Granted 17,150 74.80 16,200 74.80 Vested (21,121) 77.96 (19,588) 77.95 Forfeited (1,847) 80.23 (1,580) 79.89 Non-vested at December 31, 2021 61,620 $79.68 57,870 $79.70

Financial Information by Busi_2

Financial Information by Business Segment (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Financial Data for Business Segments	The financial data for the business segments are as follows: As of and for the Year Ended December 31, 2021 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,806 $18 $1,286 $1,802 $(84) $542 $151 $36,260 $2,189 Gas 2,378 8 326 646 (16) 179 110 13,748 1,126 Steam 532 74 93 12 (8) 41 (9) 2,647 103 Consolidation adjustments — (100) — — — — — — — Total CECONY $11,716 $— $1,705 $2,460 ($108) $762 $252 $52,655 $3,418 O&R Electric $681 $— $69 $100 $(8) $27 $13 $2,123 $147 Gas 260 — 26 50 (4) 15 8 1,169 70 Other — — — — — — — — — Total O&R $941 $— $95 $150 $(12) $42 $21 $3,292 $217 Clean Energy Businesses $1,022 $— $231 $236 $(10) $68 $44 $6,554 $298 Con Edison Transmission 4 — 1 (16) (407) 9 3 249 31 Other (b) (7) — — (4) (1) 24 20 366 — Total Con Edison $13,676 $— $2,032 $2,826 $(538) $905 $340 $63,116 $3,964 As of and for the Year Ended December 31, 2020 (Millions of Dollars) Operating revenues Inter- segment revenues Depreciation and amortization Operating income Other Income (deductions) Interest charges Income taxes on operating income (a) Total assets Capital expenditures CECONY Electric $8,103 $18 $1,214 $1,731 $(134) $535 $130 $35,673 $2,080 Gas 2,036 7 294 574 (25) 164 102 12,678 1,044 Steam 508 74 90 5 (12) 40 (14) 2,616 122 Consolidation adjustments — (99) — — — — — — — Total CECONY $10,647 $— $1,598 $2,310 $(171) $739 $218 $50,967 $3,246 O&R Electric $629 $— $65 $99 $(10) $26 $13 $2,097 $159 Gas 233 — 25 48 (4) 15 8 1,150 61 Other — — — — — — — — — Total O&R $862 $— $90 $147 $(14) $41 $21 $3,247 $220 Clean Energy Businesses $736 $— $231 $215 $4 $196 $(43) $6,848 $616 Con Edison Transmission 4 — 1 (8) (215) 18 — 1,348 3 Other (b) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 As of and for the Year Ended December 31, 2019 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $8,062 $17 $1,053 $1,758 $(28) $539 $239 $32,988 $1,851 Gas 2,132 7 231 528 (4) 147 99 11,090 1,078 Steam 627 70 89 62 (3) 42 4 2,479 91 Consolidation adjustments — (94) — — — — — — — Total CECONY $10,821 $— $1,373 $2,348 $(35) $728 $342 $46,557 $3,020 O&R Electric $634 $— $60 $98 $(7) $27 $15 $2,130 $142 Gas 259 — 24 41 (4) 14 6 876 61 Other — — — — — — — — — Total O&R $893 $— $84 $139 $(11) $41 $21 $3,006 $203 Clean Energy Businesses $857 $— $226 $202 $5 $186 $(58) $6,528 $248 Con Edison Transmission 4 — 1 (6) 104 25 1 1,618 205 Other (b) (1) — — (7) (12) 11 (6) 370 — Total Con Edison $12,574 $— $1,684 $2,676 $51 $991 $300 $58,079 $3,676 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $(150) million, $(103) million and $(4) million in 2021, 2020 and 2019, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(6) million, $(3) million and $(7) million in 2021, 2020 and 2019, respectively. (b) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Offsetting of Assets	The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2021 and 2020 were: (Millions of Dollars) 2021 2020 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $285 $(158) $127 (b) $44 $14 $58 (b) Noncurrent 90 (13) 77 22 35 57 (d) Total fair value of derivative assets $375 $(171) $204 $66 $49 $115 Fair value of derivative liabilities Current $(289) $137 $(152) (c) $(225) $(13) $(238) (d) Noncurrent (94) 10 (84) (c) (207) (33) (240) (d) Total fair value of derivative liabilities $(383) $147 $(236) $(432) $(46) $(478) Net fair value derivative assets/(liabilities) $(8) $(24) $(32) $(366) $3 $(363) CECONY Fair value of derivative assets Current $135 $(64) $71 (b) $20 $(12) $8 (b) Noncurrent 71 (15) 56 16 (8) 8 Total fair value of derivative assets $206 $(79) $127 $36 $(20) $16 Fair value of derivative liabilities Current $(131) $43 $(88) $(174) $11 $(163) Noncurrent (50) 10 (40) (114) 9 (105) Total fair value of derivative liabilities $(181) $53 $(128) $(288) $20 $(268) Net fair value derivative assets/(liabilities) $25 ($26) $(1) $(252) $— $(252) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2021 and 2020, margin deposits for Con Edison ($1 million and $3 million, respectively) and CECONY (an immaterial amount and $3 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer. (d) Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.
Offsetting of Liabilities	The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2021 and 2020 were: (Millions of Dollars) 2021 2020 Balance Sheet Location Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Gross Amounts of Recognized Assets/ (Liabilities) Gross Amounts Offset Net Amounts of Assets/(Liabilities) (a) Con Edison Fair value of derivative assets Current $285 $(158) $127 (b) $44 $14 $58 (b) Noncurrent 90 (13) 77 22 35 57 (d) Total fair value of derivative assets $375 $(171) $204 $66 $49 $115 Fair value of derivative liabilities Current $(289) $137 $(152) (c) $(225) $(13) $(238) (d) Noncurrent (94) 10 (84) (c) (207) (33) (240) (d) Total fair value of derivative liabilities $(383) $147 $(236) $(432) $(46) $(478) Net fair value derivative assets/(liabilities) $(8) $(24) $(32) $(366) $3 $(363) CECONY Fair value of derivative assets Current $135 $(64) $71 (b) $20 $(12) $8 (b) Noncurrent 71 (15) 56 16 (8) 8 Total fair value of derivative assets $206 $(79) $127 $36 $(20) $16 Fair value of derivative liabilities Current $(131) $43 $(88) $(174) $11 $(163) Noncurrent (50) 10 (40) (114) 9 (105) Total fair value of derivative liabilities $(181) $53 $(128) $(288) $20 $(268) Net fair value derivative assets/(liabilities) $25 ($26) $(1) $(252) $— $(252) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At December 31, 2021 and 2020, margin deposits for Con Edison ($1 million and $3 million, respectively) and CECONY (an immaterial amount and $3 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Includes amounts for interest rate swaps of $4 million in noncurrent assets, $(20) million in current liabilities and $(38) million in noncurrent liabilities. At December 31, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,031 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer. (d) Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.
Realized and Unrealized Gains or Losses on Commodity Derivatives	The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the years ended December 31, 2021 and 2020: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2021 2020 2021 2020 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $134 $(26) $124 $(27) Noncurrent Deferred derivative gains 57 — 51 — Total deferred gains/(losses) $191 $(26) $175 $(27) Current Deferred derivative losses $49 $(63) $43 $(64) Current Recoverable energy costs 3 (201) — (177) Noncurrent Deferred derivative losses 70 (37) 66 (36) Total deferred gains/(losses) $122 $(301) $109 $(277) Net deferred gains/(losses) $313 $(327) $284 $(304) Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $18 $(2) $— $— Non-utility revenue 3 7 — — Other operations and maintenance expense 5 (3) 5 (3) Other interest expense 52 (65) — — Total pre-tax gain/(loss) recognized in income $78 $(63) $5 $(3)
Hedged Volume of Derivative Transactions	The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2021: Electric Energy Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 26,982,370 42,333 253,195,063 3,696,000 CECONY 24,646,000 28,800 235,570,000 3,696,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes.
Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features	The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2021: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $158 $121 Collateral posted 170 170 Additional collateral (b) (downgrade one level from current ratings) 43 1 Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 94 37 (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $5 million at December 31, 2021. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset. (c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2021, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $66 million.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis	For information on the measurement of Con Edison's investment in MVP, which was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2021 and 2020 are summarized below. 2021 2020 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $95 $260 $17 $(171) $201 $19 $42 $4 $53 $118 Interest rate swaps (a)(b)(c)(f) — 4 — — 4 — — — — — Other (a)(b)(d) 492 135 — — 627 431 126 — — 557 Total assets $587 $399 $17 $(171) $832 $450 $168 $4 $53 $675 Derivative liabilities: Commodity (a)(b)(c) $33 $266 $28 $(148) $179 $7 $296 $23 $46 $372 Interest rate swaps (a)(b)(c)(f) — 57 — — 57 — 106 — — 106 Total liabilities $33 $323 $28 $(148) $236 $7 $402 $23 $46 $478 CECONY Derivative assets: Commodity (a)(b)(c) $67 $138 $1 $(79) $127 $15 $20 $— $(16) $19 Other (a)(b)(d) 474 127 — — 601 411 120 — — 531 Total assets $541 $265 $1 $(79) $728 $426 $140 $— $(16) $550 Derivative liabilities: Commodity (a)(b)(c) $1 $172 $8 $(53) $128 $3 $274 $10 $(19) $268 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Con Edison and CECONY had $1 million of commodity derivative assets and $4 million and $3 million of commodity derivative liabilities, respectively, transferred from level 3 to level 2 during the year ended December 31, 2021 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2021 to less than three years as of December 31, 2021. Con Edison and CECONY had $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2020 to less than three years as of December 31, 2020. (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs, such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2021 and 2020, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. (f) See Note Q.
Schedule of Commodity Derivatives	Fair Value of Level 3 at December 31, 2021 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity $(6) Discounted Cash Flow Forward energy prices (a) $18.75-$82.40 per MWh (10) Discounted Cash Flow Forward capacity prices (a) $0.31-$12.93 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 5 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(20.27)-$83.04 per MWh Total Con Edison — Commodity $(11) CECONY — Commodity Electricity $(8) Discounted Cash Flow Forward capacity prices (a) $1.35-$12.93 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.52-$3.63 per MWh Total CECONY — Commodity $(7) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.
Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value	The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2021 and 2020 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2021 2020 2021 2020 Beginning balance as of January 1, $(19) $(16) $(10) $(6) Included in earnings (9) (10) (3) (5) Included in regulatory assets and liabilities 3 (7) 1 (4) Purchases 6 — — — Settlements 5 15 3 6 Transfer out of level 3 3 (1) 2 (1) Ending balance as of December 31, $(11) $(19) $(7) $(10)

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Business Acquisitions, by Acquisition	At December 31, 2021 and 2020, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar CED Nevada Virginia (c)(h) (Millions of Dollars) 2021 2020 2021 2020 2021 Non-utility property, less accumulated depreciation (f)(g) $275 $284 $431 $446 $643 Other assets 37 39 167 176 55 Total assets (a) $312 $323 $598 $622 $698 Other liabilities 14 13 74 71 315 Total liabilities (b) $14 $13 $74 $71 $315 (a) The assets of the Tax Equity Projects and CED Nevada Virginia represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects and CED Nevada Virginia represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $84 million and $82 million at December 31, 2021 and 2020, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $118 million and $134 million at December 31, 2021 and 2020, respectively. (f) Non-utility property is reduced by accumulated depreciation of $26 million for Great Valley Solar, $44 million for Copper Mountain - Mesquite Solar and $10 million for CED Nevada Virginia at December 31, 2021. (g) Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020. (h) CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $95 million at December 31, 2021.
Summary of VIEs	The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2021: Project Name Generating Capacity (a) (MW AC) Power Purchase Agreement Term in Years Year of Investment Location Maximum Millions of Dollars ) (b) Great Valley Solar (c) 200 15-20 2018 CA $214 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 NV and AZ 406 CED Nevada Virginia (c) 431 20-25 2021 NV and VA 288 (a) Represents ownership interest in the project. (b) Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (c) For the projects comprising Great Valley Solar, Copper Mountain Mesquite Solar and CED Nevada Virginia, refer to (d), (e) and (h) in the table above.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
Summary of Costs of Administrative and Other Services Provided and Received	The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2021, 2020 and 2019 were as follows: CECONY (Millions of Dollars) 2021 2020 2019 Cost of services provided $137 $128 $121 Cost of services received 68 66 64

General (Details)

General (Details)	12 Months Ended
	Dec. 31, 2021subsidiaryregistrant
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of registrants | registrant	2
Number of regulated subsidiaries | subsidiary	2

Summary of Significant Accoun_4

Summary of Significant Accounting Policies and Other Matters - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenue from External Customer [Line Items]
Excise taxes	$ 358	$ 335	$ 323
CECONY
Revenue from External Customer [Line Items]
Excise taxes	$ 346	$ 323	$ 312

Summary of Significant Accoun_5

Summary of Significant Accounting Policies and Other Matters - Plant and Depreciation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Public Utility, Property, Plant and Equipment [Line Items]
Accumulated amortization	$ 297	$ 228
Annual aggregate depreciation allowance	1,802
Prepayments	16	12
Other deferred charges and noncurrent assets	81	54
Depreciation expense, other deferred charges and noncurrent assets and prepayments	12	7
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	22	10
Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	79	86
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 24	$ 17
Non-Utility Plant | Maximum | Land And Conduit
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	10 years
Non-Utility Plant | Maximum | Wind Power Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	30 years
Non-Utility Plant | Maximum | Solar Powered Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	35 years
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	4.50%	5.20%	5.10%
Average depreciation rates (percent)	3.50%	3.50%	3.20%
Annual aggregate depreciation allowance	$ 1,710
Prepayments	15	$ 11
Other deferred charges and noncurrent assets	78	51
Depreciation expense, other deferred charges and noncurrent assets and prepayments	11	6
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	19	8
CECONY | Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	74	81
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 24	$ 17
CECONY | Electric | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Electric | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	85 years
CECONY | Gas | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Gas | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	90 years
CECONY | Steam | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Steam | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	80 years
CECONY | General Plant | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | General Plant | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	55 years
O&R
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	4.80%	5.30%	5.30%
Average depreciation rates (percent)	3.10%	3.20%	3.00%
O&R | Electric | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R | Electric | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	75 years
O&R | General Plant | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R | General Plant | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	50 years

Summary of Significant Accoun_6

Summary of Significant Accounting Policies and Other Matters - Capitalized Cost of Utility Plant (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 4,170	$ 3,880
Held for future use	80	92
Construction work in progress	2,152	2,474
NET UTILITY PLANT	44,214	42,024
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	559	572
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,955	3,786
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	22,418	21,481
General
Public Utility, Property, Plant and Equipment [Line Items]
General	87	52
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	10,473	9,206
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,924	1,854
General
Public Utility, Property, Plant and Equipment [Line Items]
General	2,566	2,507
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	3,854	3,585
Held for future use	72	84
Construction work in progress	1,985	2,320
NET UTILITY PLANT	41,611	39,552
CECONY | Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	559	572
CECONY | Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,658	3,496
CECONY | Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	21,240	20,366
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	87	52
CECONY | Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	9,748	8,522
CECONY | Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,924	1,854
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,338	$ 2,286

Summary of Significant Accoun_7

Summary of Significant Accounting Policies and Other Matters - Long-Lived and Intangible Assets (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	$ 1,290,000,000	$ 1,457,000,000
Accumulated amortization	297,000,000	228,000,000
Amortization of intangible assets	95,000,000	102,000,000	$ 99,000,000
Amortization expense, 2020	95,000,000
Amortization expense, 2021	95,000,000
Amortization expense, 2022	95,000,000
Amortization expense, 2023	95,000,000
Amortization expense, 2024	95,000,000
Impairment charges	0	0
Net non-utility plant	48,596,000,000	46,555,000,000
Intangible assets	1,293,000,000	1,460,000,000
Long-term debt	23,044,000,000	22,349,000,000
Power Purchase Agreements
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	288,000,000	220,000,000
Other Intangible Assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	3,000,000	3,000,000
Accumulated amortization	$ 9,000,000	$ 8,000,000

Summary of Significant Accoun_8

Summary of Significant Accounting Policies and Other Matters - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2021
Minimum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	1 month
Maximum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	2 months

Summary of Significant Accoun_9

Summary of Significant Accounting Policies and Other Matters - Investments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)mi	Dec. 31, 2020USD ($)	Dec. 30, 2021USD ($)	Jun. 30, 2021USD ($)	May 31, 2021USD ($)	Mar. 31, 2021USD ($)	Dec. 30, 2020USD ($)	Jan. 31, 2016
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 525	$ 465
Deferred income plan assets	102	92
Other	3	3
Total investments	853	1,816
Stagecoach
Schedule of Equity Method Investments [Line Items]
Loss on sale of investment (pre-tax)	212
Loss on sale of investment	147
Equity method investments				$ 630		$ 667
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	530	530
CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	0	845
CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	111	342
CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	112	69
CET | Stagecoach | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 1,225
Equity method investment, ownership percentage	50.00%
Impairment loss	$ 414
CET Gas | Stagecoach | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	629
CECONY
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	499	439
Deferred income plan assets	102	92
Other	7	10
Total investments	608	541
CECONY | CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	0	0
CECONY | CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	0	0
CECONY | CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 0	$ 0
CET Gas | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	10.20%	11.30%
Impairment loss	$ 231	$ 320
Equity method investments		530
Number of miles in pipeline construction | mi	300
Carrying value of investment	$ 111	$ 342	$ 342				$ 662
Expected reduction in equity interest	8.50%
Project, percent completion	92.00%	94.00%
Long -term firm transportation contract period	20 years
Cash flows discount rate	8.30%
Deferred tax assets	$ 130	$ 53
Increase in deferred tax assets	77
Impairment loss, after tax	$ 162	$ 223
Aggregate project cost					$ 6,200
CET Gas | Mountain Valley Pipeline | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage								12.50%
CET Electric | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	45.70%

Summary of Significant Accou_10

Summary of Significant Accounting Policies and Other Matters - Pension and Other Postretirement Benefits (Details)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Investment gains and losses recognized, time period (years)	15 years
Other actuarial gains and losses recognized, time period (years)	10 years
Difference between fair value and expected market related value of plan assets (percent)	20.00%

Summary of Significant Accou_11

Summary of Significant Accounting Policies and Other Matters - Research and Development Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Research and Development Expenses [Line Items]
Research and development costs	$ 25	$ 24	$ 24
CECONY
Research and Development Expenses [Line Items]
Research and development costs	$ 24	$ 23	$ 23

Summary of Significant Accou_12

Summary of Significant Accounting Policies and Other Matters - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Net income	$ 1,346	$ 1,101	$ 1,343
Weighted average common shares outstanding – basic (in shares)	348.4	334.8	328.5
Add: Incremental shares attributable to effect of potentially dilutive securities (in shares)	1	0.9	1
Adjusted weighted average common shares outstanding – diluted (in shares)	349.4	335.7	329.5
Net income per common share — basic (in dollars per share)	$ 3.86	$ 3.29	$ 4.09
Net income per common share — diluted (in dollars per share)	$ 3.85	$ 3.28	$ 4.08

Summary of Significant Accou_13

Summary of Significant Accounting Policies and Other Matters - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	$ 19,065	$ 18,213	$ 16,839
BALANCE AS OF BEGINNING OF PERIOD	18,847
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	30	(6)	(3)
BALANCE AS OF END OF PERIOD	20,037	18,847
BALANCE AS OF END OF PERIOD	20,336	19,065	18,213
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(25)	(19)	(16)
BALANCE AS OF END OF PERIOD	5	(25)	(19)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	22	(11)	(10)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	8	5	7
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	30	(6)	(3)
OCI before reclassifications, tax	(8)	4	(6)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(3)	(2)	(2)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(25)	(19)	(16)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	30	(6)	(3)
BALANCE AS OF END OF PERIOD	5	(25)	(19)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	14,849	14,147	12,910
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	7	(1)	(1)
BALANCE AS OF END OF PERIOD	16,312	14,849	14,147
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(7)	(6)	(5)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	7	(1)	(1)
BALANCE AS OF END OF PERIOD	0	(7)	(6)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	5	(3)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	2	2	2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	7	(1)	(1)
OCI before reclassifications, tax	(2)	$ 1	$ (1)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	$ (1)

Summary of Significant Accou_14

Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 992	$ 1,272
Restricted cash	154	164
Total cash, temporary cash investments and restricted cash	1,146	1,436	$ 1,217	$ 1,006
Cash Collateral Held For Project Finance Agreements | Clean Energy Businesses
Cash and Cash Equivalents [Line Items]
Restricted cash	154	164
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	920	1,067
Restricted cash	0	0
Total cash, temporary cash investments and restricted cash	$ 920	$ 1,067	$ 933	$ 818

Regulatory Matters - Summary of

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Details) - USD ($)	1 Months Ended					12 Months Ended						36 Months Ended
	Jan. 31, 2025	Jan. 31, 2024	Jan. 31, 2022	Nov. 30, 2021	Dec. 31, 2016	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2016	Dec. 31, 2024
Public Utilities, General Disclosures [Line Items]
Revenues						$ 13,676,000,000	$ 12,246,000,000	$ 12,574,000,000
Deferred revenues						7,000,000	41,000,000	17,000,000	$ 20,000,000				$ 17,000,000
Deferred revenues						$ (662,000,000)	(599,000,000)
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues						15.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues						15.00%
Percentage of debt to total consolidated debt						20.00%
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues						$ 11,716,000,000	10,647,000,000	10,821,000,000
Deferred revenues						(549,000,000)	(523,000,000)
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues													75,000,000
Actual earnings adjustment mechanism incentives						64,000,000	34,000,000	43,000,000	25,000,000	$ 13,000,000
Other earnings incentives								5,000,000	5,000,000	5,000,000
Deferred revenues						226,000,000	242,000,000	169,000,000	(6,000,000)	45,000,000			169,000,000
Negative revenue adjustments						0	5,000,000	15,000,000	0	0
Cost reconciliation, deferred net regulatory liabilities						191,000,000	288,000,000	10,000,000	189,000,000	35,000,000			10,000,000
Deferred regulatory asset (liability)						3,200,000	4,100,000	(11,800,000)	(400,000)	400,000			$ (11,800,000)
Earnings sharing, threshold limit							$ 0	0		$ 0
Earnings sharing, positive adjustment						$ 4,300,000					$ 5,700,000
Common equity ratio, percentage													48.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan					$ 48,000,000
Recovery or refund of energy costs, deferral period													10 years
Deferrals for property taxes limitation from rates (percent)														90.00%
Recovery deferral (percent)						80.00%
Maximum deferral (percent)						30.00%
CECONY | Electric | NYSPSC
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 199,000,000
Actual return on common equity (percent)							8.81%
Amount of cost recovery				$ 43,000,000		19,000,000	$ 43,000,000
CECONY | Electric | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 1,199,000,000
Return on common equity (percent)			10.00%
Common equity ratio			50.00%
CECONY | Electric | Service Termination
Public Utilities, General Disclosures [Line Items]
Revenues								$ 7,000,000	$ 3,000,000
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues												$ 75,000,000
Authorized return on common equity (percent)												8.80%
Earnings sharing (percent)															9.30%
Common equity ratio, percentage												48.00%
Maximum deferral (percent)															15.00%
CECONY | Electric | Scenario, Forecast | NYSPSC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 608,000,000	$ 853,000,000
Return on common equity (percent)		10.00%
Common equity ratio		50.00%
CECONY | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 195,000,000
Utilities operating expense, depreciation and amortization													$ 84,000,000
Potential earnings adjustment mechanism incentives													28,000,000
Average rate base													$ 18,902,000,000
Weighted average cost of capital (after-tax) (percent)													6.82%
Authorized return on common equity (percent)													9.00%
Actual return on common equity (percent)													9.30%
Earnings sharing (percent)						9.50%
Cost of long-term debt rate						4.93%
Recovery of energy efficiency and savings program costs													$ 20,500,000
Deferral, annual maximum (not more than) (percent)														10.00%
CECONY | Electric | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													21,689,000,000
CECONY | Electric | Year 1 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													126,000,000
CECONY | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)													376,000,000
CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 113,000,000
Utilities operating expense, depreciation and amortization												$ 267,000,000
Potential earnings adjustment mechanism incentives												69,000,000
Potential penalties (annually)												450,000,000
Average rate base												$ 21,660,000,000
Weighted average cost of capital (after-tax) (percent)												6.61%
Actual return on common equity (percent)												8.50%
Cost of long-term debt rate															4.63%
Amount of cost recovery												$ 206,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												24,491,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												572,000,000
CECONY | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 155,000,000
Utilities operating expense, depreciation and amortization													83,000,000
Potential earnings adjustment mechanism incentives													47,000,000
Average rate base													$ 19,530,000,000
Weighted average cost of capital (after-tax) (percent)													6.80%
Actual return on common equity (percent)													9.36%
Cost of long-term debt rate						4.88%
Recovery of energy efficiency and savings program costs													$ 49,000,000
Deferral, annual maximum (not more than) (percent)														7.50%
CECONY | Electric | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													22,338,000,000
CECONY | Electric | Year 2 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													257,000,000
CECONY | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)													341,000,000
CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 370,000,000
Utilities operating expense, depreciation and amortization												269,000,000
Potential earnings adjustment mechanism incentives												74,000,000
Potential penalties (annually)												461,000,000
Average rate base												$ 22,783,000,000
Actual return on common equity (percent)												8.03%
Amount of cost recovery												$ 245,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												25,092,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												740,000,000
CECONY | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 155,000,000
Utilities operating expense, depreciation and amortization													69,000,000
Potential earnings adjustment mechanism incentives													64,000,000
Average rate base													$ 20,277,000,000
Weighted average cost of capital (after-tax) (percent)													6.73%
Actual return on common equity (percent)													8.82%
Cost of long-term debt rate						4.74%
Recovery of energy efficiency and savings program costs													$ 107,500,000
Deferral, annual maximum (not more than) (percent)														5.00%
CECONY | Electric | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													23,002,000,000
CECONY | Electric | Year 3 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations													415,000,000
CECONY | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)													$ 352,000,000
CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes															$ 326,000,000
Utilities operating expense, depreciation and amortization												272,000,000
Potential earnings adjustment mechanism incentives												79,000,000
Potential penalties (annually)												476,000,000
Average rate base												23,926,000,000
Amount of cost recovery												251,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												25,708,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												806,000,000
Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA												126,000,000
Annually | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization												48,000,000
Over Five Years | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization												238,000,000
Over Three Years | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA												377,000,000
Protected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												1,663,000,000
Protected Portion | CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												49,000,000
Protected Portion | CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												50,000,000
Protected Portion | CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												53,000,000
Unprotected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												$ 784,000,000
TCJA of 2017 regulatory liabilities, income tax benefit, amortization period												5 years
Unprotected Portion | Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA												$ 157,000,000

Regulatory Matters - Summary _2

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Details) - USD ($)	1 Months Ended					12 Months Ended					36 Months Ended
	Jan. 31, 2025	Jan. 31, 2024	Jan. 31, 2022	Nov. 30, 2021	Dec. 31, 2016	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2016	Dec. 31, 2024	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Revenues						$ 13,676,000,000	$ 12,246,000,000	$ 12,574,000,000
Deferred revenues						7,000,000	41,000,000	17,000,000	$ 20,000,000			$ 17,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues						11,716,000,000	10,647,000,000	10,821,000,000
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve												15.00%
Other earnings incentives						26,000,000	3,000,000	7,000,000	6,000,000	$ 7,000,000
Deferred revenues						100,000,000	27,000,000	10,000,000	12,000,000	3,000,000		$ 10,000,000
Negative revenue adjustments						0	0	0	4,000,000	5,000,000
Cost reconciliation, deferred net regulatory liabilities						14,000,000	91,000,000	18,000,000	44,000,000	2,000,000		18,000,000
Deferred regulatory asset (liability)						(26,000,000)	(24,700,000)	$ (1,700,000)	(2,200,000)	(2,200,000)		$ (1,700,000)
Earnings sharing (percent)								9.50%				9.50%
Earnings sharing, threshold limit						0	0	$ 0	0	0
Common equity ratio, percentage												48.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan					$ 41,000,000
CECONY | Gas | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained							65,000,000
CECONY | Gas | Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
Revenues						$ 7,000,000	13,000,000	9,000,000	5,000,000
CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve											15.00%
Earnings sharing (percent)														9.30%
Common equity ratio, percentage											48.00%
CECONY | Gas | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained															$ 65,000,000
CECONY | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes												$ (5,000,000)
Utilities operating expense, depreciation and amortization												39,000,000
Potential incentives if performance targets are met												7,000,000
Potential penalties (annually)												68,000,000
Average rate base												$ 4,841,000,000
Weighted average cost of capital (after-tax) (percent)												6.82%
Authorized return on common equity (percent)												9.00%
Actual return on common equity (percent)												9.22%
Cost of long-term debt rate						4.93%
CECONY | Gas | Year 1 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												$ 5,844,000,000
CECONY | Gas | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												27,000,000
CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes											$ 84,000,000
Utilities operating expense, depreciation and amortization											45,000,000
Potential incentives if performance targets are met											20,000,000
Potential penalties (annually)											81,000,000
Average rate base											$ 7,171,000,000
Weighted average cost of capital (after-tax) (percent)											6.61%
Authorized return on common equity (percent)											8.80%
Actual return on common equity (percent)											8.40%
Cost of long-term debt rate											4.63%
CECONY | Gas | Year 1 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											$ 8,108,000,000
CECONY | Gas | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											142,000,000
CECONY | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes												92,000,000
Utilities operating expense, depreciation and amortization												37,000,000
Potential incentives if performance targets are met												8,000,000
Potential penalties (annually)												63,000,000
Average rate base												$ 5,395,000,000
Weighted average cost of capital (after-tax) (percent)												6.80%
Actual return on common equity (percent)												9.04%
Cost of long-term debt rate						4.88%
CECONY | Gas | Year 2 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												$ 6,512,000,000
CECONY | Gas | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												57,000,000
CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes											122,000,000
Utilities operating expense, depreciation and amortization											43,000,000
Potential incentives if performance targets are met											22,000,000
Potential penalties (annually)											88,000,000
Average rate base											$ 7,911,000,000
Actual return on common equity (percent)											8.48%
CECONY | Gas | Year 2 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											$ 8,808,000,000
CECONY | Gas | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											183,000,000
CECONY | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes												90,000,000
Utilities operating expense, depreciation and amortization												36,000,000
Potential incentives if performance targets are met												8,000,000
Potential penalties (annually)												70,000,000
Average rate base												$ 6,005,000,000
Weighted average cost of capital (after-tax) (percent)												6.73%
Actual return on common equity (percent)												8.72%
Cost of long-term debt rate						4.74%
CECONY | Gas | Year 3 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												$ 7,177,000,000
CECONY | Gas | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												100,000,000
CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes											167,000,000
Utilities operating expense, depreciation and amortization											10,000,000
Potential incentives if performance targets are met											25,000,000
Potential penalties (annually)											96,000,000
Average rate base											8,622,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											9,510,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											$ 211,000,000
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Other earnings incentives								5,000,000	5,000,000	5,000,000
Deferred revenues						$ 226,000,000	242,000,000	169,000,000	(6,000,000)	45,000,000		169,000,000
Negative revenue adjustments						0	5,000,000	15,000,000	0	0
Cost reconciliation, deferred net regulatory liabilities						191,000,000	288,000,000	10,000,000	189,000,000	35,000,000		10,000,000
Deferred regulatory asset (liability)						$ 3,200,000	4,100,000	(11,800,000)	$ (400,000)	400,000		$ (11,800,000)
Earnings sharing, threshold limit							$ 0	$ 0		$ 0
Common equity ratio, percentage												48.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan					$ 48,000,000
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)											8.80%
Earnings sharing (percent)														9.30%
Common equity ratio, percentage											48.00%
CECONY | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization												$ 84,000,000
Potential incentives if performance targets are met												28,000,000
Average rate base												$ 18,902,000,000
Weighted average cost of capital (after-tax) (percent)												6.82%
Authorized return on common equity (percent)												9.00%
Actual return on common equity (percent)												9.30%
Earnings sharing (percent)						9.50%
Cost of long-term debt rate						4.93%
Deferral, annual maximum (not more than) (percent)													10.00%
Recovery of energy efficiency and savings program costs												$ 20,500,000
CECONY | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)												376,000,000
CECONY | Electric | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												126,000,000
CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization											$ 267,000,000
Potential incentives if performance targets are met											69,000,000
Potential penalties (annually)											450,000,000
Average rate base											$ 21,660,000,000
Weighted average cost of capital (after-tax) (percent)											6.61%
Actual return on common equity (percent)											8.50%
Cost of long-term debt rate														4.63%
Amount of cost recovery											$ 206,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											572,000,000
CECONY | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization												83,000,000
Potential incentives if performance targets are met												47,000,000
Average rate base												$ 19,530,000,000
Weighted average cost of capital (after-tax) (percent)												6.80%
Actual return on common equity (percent)												9.36%
Cost of long-term debt rate						4.88%
Deferral, annual maximum (not more than) (percent)													7.50%
Recovery of energy efficiency and savings program costs												$ 49,000,000
CECONY | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)												341,000,000
CECONY | Electric | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												257,000,000
CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization											269,000,000
Potential incentives if performance targets are met											74,000,000
Potential penalties (annually)											461,000,000
Average rate base											$ 22,783,000,000
Actual return on common equity (percent)											8.03%
Amount of cost recovery											$ 245,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											740,000,000
CECONY | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization												69,000,000
Potential incentives if performance targets are met												64,000,000
Average rate base												$ 20,277,000,000
Weighted average cost of capital (after-tax) (percent)												6.73%
Actual return on common equity (percent)												8.82%
Cost of long-term debt rate						4.74%
Deferral, annual maximum (not more than) (percent)													5.00%
Recovery of energy efficiency and savings program costs												$ 107,500,000
CECONY | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)												352,000,000
CECONY | Electric | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations												$ 415,000,000
CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization											272,000,000
Potential incentives if performance targets are met											79,000,000
Potential penalties (annually)											476,000,000
Average rate base											23,926,000,000
Amount of cost recovery											251,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations											806,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues						15.00%
NYSPSC | Maximum
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues						15.00%
Percentage of debt to total consolidated debt						20.00%
NYSPSC | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)							8.56%
Amount of cost recovery				$ 7,000,000		$ 4,000,000	$ 7,000,000
NYSPSC | CECONY | Gas | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization			$ 48,000,000
Requested rate increase (decrease), amount			$ 503,000,000
Return on common equity (percent)			10.00%
Common equity ratio			50.00%
NYSPSC | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 218,000,000	$ 234,000,000
Return on common equity (percent)		10.00%
Common equity ratio		50.00%
NYSPSC | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)							8.81%
Amount of cost recovery				$ 43,000,000		$ 19,000,000	$ 43,000,000
NYSPSC | CECONY | Electric | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 1,199,000,000
Return on common equity (percent)			10.00%
Common equity ratio			50.00%
NYSPSC | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 608,000,000	$ 853,000,000
Return on common equity (percent)		10.00%
Common equity ratio		50.00%
Annually | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											32,000,000
Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											126,000,000
Over Ten Years | CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											47,000,000
Amount of cost recovery											30,000,000
Over Ten Years | CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											176,000,000
Amount of cost recovery											37,000,000
Over Ten Years | CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											170,000,000
Amount of cost recovery											40,000,000
Over Two Years | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											63,000,000
Protected Portion | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											725,000,000
Protected Portion | CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											14,000,000
Protected Portion | CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											14,000,000
Protected Portion | CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											12,000,000
Protected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											1,663,000,000
Protected Portion | CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											49,000,000
Protected Portion | CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											50,000,000
Protected Portion | CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											53,000,000
Unprotected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 784,000,000
TCJA of 2017 regulatory liabilities, income tax benefit, amortization period											5 years
Unprotected Portion | Annually | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 21,000,000
Unprotected Portion | Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											157,000,000
Unprotected Portion | Over Five Years | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 107,000,000

Regulatory Matters - Summary _3

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Details) - CECONY - Steam - USD ($)	12 Months Ended								36 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization									$ 37,000,000
Regulatory liabilities, amortization period									3 years
Negative revenue adjustments	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Cost reconciliation, deferred net regulatory liabilities					14,000,000	8,000,000		$ 42,000,000	$ 8,000,000
Cost reconciliation, deferred net regulatory assets	32,000,000	35,000,000	8,000,000	1,000,000			$ 17,000,000
Increase (decrease) in regulatory liabilities	(600,000)	(1,600,000)	0	$ 0	0			(100,000)
Authorized return on common equity (percent)									9.30%
Earnings sharing (percent)				9.90%
Earnings sharing, threshold limit	$ 0	$ 0	$ 5,000,000	$ 16,500,000	8,500,000	7,800,000	$ 11,500,000	$ 0
Earnings sharing, positive adjustment				2,300,000	$ 1,100,000	4,000,000
Earnings sharing, additional adjustment				200,000		$ 400,000
Common equity ratio, percentage									48.00%
Other regulatory liabilities				$ 8,000,000
Difference in property taxes (percent)									90.00%
Deferral, annual maximum (not more than) (percent)									10.00%
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ (22,400,000)
Average rate base									$ 1,511,000,000
Weighted average cost of capital (after-tax) (percent)									7.10%
Actual return on common equity (percent)									9.82%
Cost of long-term debt rate						5.17%			5.17%
Year 1 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,752,000,000
Year 1 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									6,000,000
Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									1,000,000
Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes									19,800,000
Average rate base									$ 1,547,000,000
Weighted average cost of capital (after-tax) (percent)									7.13%
Actual return on common equity (percent)									10.88%
Cost of long-term debt rate						5.23%			5.23%
Year 2 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,732,000,000
Year 2 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									11,000,000
Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									1,000,000
Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes									20,300,000
Average rate base									$ 1,604,000,000
Weighted average cost of capital (after-tax) (percent)									7.21%
Actual return on common equity (percent)									10.54%
Cost of long-term debt rate						5.39%			5.39%
Year 3 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,720,000,000
Year 3 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									25,000,000
Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									1,000,000
Year 4
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0
Actual return on common equity (percent)									9.51%
Year 5
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0
Actual return on common equity (percent)									11.73%
Year 6
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0
Actual return on common equity (percent)									10.45%
Year 7
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0
Actual return on common equity (percent)									7.91%
Year 8
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ 0
Actual return on common equity (percent)									5.99%

Regulatory Matters - Summary _4

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended			36 Months Ended
	Oct. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2024	Dec. 31, 2021	Dec. 31, 2018
Public Utilities, General Disclosures [Line Items]
Deferred revenues		$ 662,000,000	$ 599,000,000			$ 662,000,000
Deferred revenues		$ 7,000,000	41,000,000	$ 17,000,000		$ 7,000,000	$ 20,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%				15.00%
Percentage of debt to total consolidated debt		20.00%				20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%				15.00%
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Deferred revenues			6,000,000	100,000
Deferred revenues		$ 10,000,000				$ 10,000,000
Negative revenue adjustments		0	0	0
Deferral of net increase (decrease) to regulatory assets		$ 24,000,000	30,300,000	4,300,000
Deferred regulatory asset (liability)			(400,000)
Earnings sharing (percent)		9.60%				9.60%
Common equity ratio, percentage						48.00%
Deferrals for property taxes limitation from rates (percent)						90.00%
O&R | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ 13,400,000
Amortization to income of net regulatory assets						(1,500,000)
Potential earnings adjustment mechanism incentives						3,600,000
Potential incentive if target is met, related to service terminations						500,000
Average rate base						$ 878,000,000
Weighted average cost of capital (after-tax) (percent)						6.97%
Actual return on common equity (percent)						9.60%
Cost of long-term debt (percent)						5.17%
Requested rate increase (decrease), amount						$ 8,600,000
Deferral, annual maximum (not more than) (percent)						10.00%
O&R | Electric | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,008,000,000
O&R | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,400,000
O&R | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						8,000,000
Amortization to income of net regulatory assets						(1,500,000)
Potential earnings adjustment mechanism incentives						4,000,000
Potential incentive if target is met, related to service terminations						500,000
Average rate base						$ 906,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						8.76%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 12,100,000
Deferral, annual maximum (not more than) (percent)						7.50%
O&R | Electric | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,032,000,000
O&R | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,400,000
O&R | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						5,800,000
Amortization to income of net regulatory assets						(1,500,000)
Potential earnings adjustment mechanism incentives						4,200,000
Potential incentive if target is met, related to service terminations						500,000
Average rate base						$ 948,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						9.16%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 12,200,000
Deferral, annual maximum (not more than) (percent)						5.00%
O&R | Electric | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 1,083,000,000
O&R | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,500,000
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)					9.70%
O&R | Electric | Scenario, Forecast | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 4,900,000
Amortization to income of net regulatory assets					(11,800,000)
Potential earnings adjustment mechanism incentives					3,300,000
Net utility plant reconciliations					1,175,000,000
Average rate base					$ 1,021,000,000
Weighted average cost of capital (after-tax) (percent)					6.77%
Cost of long-term debt (percent)					4.58%
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,300,000
O&R | Electric | Scenario, Forecast | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes					16,200,000
Amortization to income of net regulatory assets					(13,500,000)
Potential earnings adjustment mechanism incentives					2,300,000
Net utility plant reconciliations					1,198,000,000
Average rate base					$ 1,044,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.51%
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,400,000
O&R | Electric | Scenario, Forecast | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes					23,100,000
Amortization to income of net regulatory assets					(15,200,000)
Potential earnings adjustment mechanism incentives					4,000,000
Net utility plant reconciliations					1,304,000,000
Average rate base					$ 1,144,000,000
Weighted average cost of capital (after-tax) (percent)					6.72%
Cost of long-term debt (percent)					4.49%
Requested rate increase (decrease), amount					$ 11,700,000
O&R | Electric | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 5,100,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Potential earnings adjustment mechanism incentives						300,000
Deferred revenues		$ 4,000,000	500,000	800,000		$ 4,000,000
Negative revenue adjustments				200,000
Earnings sharing (percent)		9.60%				9.60%
Common equity ratio, percentage						48.00%
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes						$ (7,500,000)
Amortization to income of net regulatory assets						(1,800,000)
Potential earnings adjustment mechanism incentives						1,200,000
Net utility plant reconciliations						593,000,000
Average rate base						$ 454,000,000
Weighted average cost of capital (after-tax) (percent)						6.97%
Actual return on common equity (percent)						8.90%
Cost of long-term debt (percent)						5.17%
Requested rate increase (decrease), amount						$ (5,900,000)
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						5,500,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						3,600,000
Amortization to income of net regulatory assets						(1,800,000)
Potential earnings adjustment mechanism incentives						1,300,000
Net utility plant reconciliations						611,000,000
Average rate base						$ 476,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						9.58%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 1,000,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						5,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						700,000
Amortization to income of net regulatory assets						(1,800,000)
Potential earnings adjustment mechanism incentives						1,300,000
Net utility plant reconciliations						632,000,000
Average rate base						$ 498,000,000
Weighted average cost of capital (after-tax) (percent)						6.96%
Actual return on common equity (percent)						10.11%
Cost of long-term debt (percent)						5.14%
Requested rate increase (decrease), amount						$ 1,000,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 6,000,000
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)					9.70%
Deferrals for property taxes limitation from rates (percent)					90.00%
O&R | Gas | Scenario, Forecast | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 700,000
Amortization to income of net regulatory assets					(800,000)
Potential earnings adjustment mechanism incentives					200,000
Net utility plant reconciliations					720,000,000
Average rate base					$ 566,000,000
Weighted average cost of capital (after-tax) (percent)					6.77%
Cost of long-term debt (percent)					4.58%
Requested rate increase (decrease), amount					$ 4,400,000
Deferral, annual maximum (not more than) (percent)					0.10%
O&R | Gas | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 6,300,000
O&R | Gas | Scenario, Forecast | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes					7,400,000
Amortization to income of net regulatory assets					(700,000)
Potential earnings adjustment mechanism incentives					200,000
Net utility plant reconciliations					761,000,000
Average rate base					$ 607,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.51%
Requested rate increase (decrease), amount					$ 4,400,000
Deferral, annual maximum (not more than) (percent)					0.075%
O&R | Gas | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 6,700,000
O&R | Gas | Scenario, Forecast | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes					9,900,000
Amortization to income of net regulatory assets					(300,000)
Potential earnings adjustment mechanism incentives					400,000
Net utility plant reconciliations					803,000,000
Average rate base					$ 649,000,000
Weighted average cost of capital (after-tax) (percent)					6.72%
Cost of long-term debt (percent)					4.49%
Requested rate increase (decrease), amount					$ 4,400,000
Deferral, annual maximum (not more than) (percent)					0.05%
O&R | Gas | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 7,300,000
O&R | Electric and Gas Transmission Projects
Public Utilities, General Disclosures [Line Items]
Recovery of late payment charges, period	3 years
Recovery of late payment charges, amount	$ 2,800,000
Recovery of late payment charges, return on equity threshold rate	0.05%
Energy Efficiency | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 1,800,000	1,900,000	2,600,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		500,000
Service Termination | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		0	500,000	200,000
Incentives reversed		500,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		200,000	$ 300,000	$ 700,000
Incentives reversed		$ 300,000

Regulatory Matters - Summary _5

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($)	12 Months Ended			36 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2024	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Deferred revenues	$ 662,000,000	$ 599,000,000			$ 662,000,000
Earnings above threshold	$ 1,700,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15.00%				15.00%
Percentage of debt to total consolidated debt	20.00%				20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues	15.00%				15.00%
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained	$ 4,000,000				$ 4,000,000
Share in variances in annual revenue retained (percent)					20.00%
Potential earnings adjustment mechanism incentives					$ 300,000
Deferred revenues	4,000,000	500,000	$ 800,000		4,000,000
Negative revenue adjustments			200,000
Cost reconciliation, deferred net regulatory liabilities			6,000,000
Cost reconciliation, deferred net regulatory assets	$ 8,000,000	1,800,000			$ 8,000,000
Earnings sharing (percent)	9.60%				9.60%
Common equity ratio, percentage					48.00%
O&R | Gas | Customers
Public Utilities, General Disclosures [Line Items]
Share in variances in annual revenue retained (percent)					80.00%
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)				9.70%
Deferrals for property taxes limitation from rates (percent)				90.00%
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ (7,500,000)
Amortization to income of net regulatory assets					1,800,000
Potential earnings adjustment mechanism incentives					1,200,000
Net utility plant reconciliations					593,000,000
Average rate base					$ 454,000,000
Weighted average cost of capital (after-tax) (percent)					6.97%
Actual return on common equity (percent)					8.90%
Cost of long-term debt (percent)					5.17%
Requested rate increase (decrease), amount					$ (5,900,000)
O&R | Gas | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					20,000,000
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					5,500,000
O&R | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 700,000
Amortization to income of net regulatory assets				800,000
Potential earnings adjustment mechanism incentives				200,000
Potential positive rate adjustment for gas safety and performance				1,200,000
Net utility plant reconciliations				720,000,000
Average rate base				$ 566,000,000
Weighted average cost of capital (after-tax) (percent)				6.77%
Cost of long-term debt (percent)				4.58%
Requested rate increase (decrease), amount				$ 4,400,000
Deferral, annual maximum (not more than) (percent)				0.10%
O&R | Gas | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				$ 6,300,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes					3,600,000
Amortization to income of net regulatory assets					1,800,000
Potential earnings adjustment mechanism incentives					1,300,000
Net utility plant reconciliations					611,000,000
Average rate base					$ 476,000,000
Weighted average cost of capital (after-tax) (percent)					6.96%
Actual return on common equity (percent)					9.58%
Cost of long-term debt (percent)					5.14%
Requested rate increase (decrease), amount					$ 1,000,000
O&R | Gas | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					24,000,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					5,700,000
O&R | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				7,400,000
Amortization to income of net regulatory assets				700,000
Potential earnings adjustment mechanism incentives				200,000
Potential positive rate adjustment for gas safety and performance				1,300,000
Net utility plant reconciliations				761,000,000
Average rate base				$ 607,000,000
Weighted average cost of capital (after-tax) (percent)				6.73%
Cost of long-term debt (percent)				4.51%
Requested rate increase (decrease), amount				$ 4,400,000
Deferral, annual maximum (not more than) (percent)				0.075%
O&R | Gas | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				$ 6,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes					700,000
Amortization to income of net regulatory assets					1,800,000
Potential earnings adjustment mechanism incentives					1,300,000
Net utility plant reconciliations					632,000,000
Average rate base					$ 498,000,000
Weighted average cost of capital (after-tax) (percent)					6.96%
Actual return on common equity (percent)					10.11%
Cost of long-term debt (percent)					5.14%
Requested rate increase (decrease), amount					$ 1,000,000
O&R | Gas | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					25,000,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 6,000,000
O&R | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				9,900,000
Amortization to income of net regulatory assets				300,000
Potential earnings adjustment mechanism incentives				400,000
Potential positive rate adjustment for gas safety and performance				1,400,000
Net utility plant reconciliations				803,000,000
Average rate base				$ 649,000,000
Weighted average cost of capital (after-tax) (percent)				6.72%
Cost of long-term debt (percent)				4.49%
Requested rate increase (decrease), amount				$ 4,400,000
Deferral, annual maximum (not more than) (percent)				0.05%
O&R | Gas | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				$ 7,300,000
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Deferred revenues		6,000,000	100,000
Negative revenue adjustments	$ 0	0	0
Earnings sharing (percent)	9.60%				9.60%
Common equity ratio, percentage					48.00%
Deferrals for property taxes limitation from rates (percent)					90.00%
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Earnings sharing (percent)				9.70%
O&R | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 13,400,000
Amortization to income of net regulatory assets					1,500,000
Potential earnings adjustment mechanism incentives					3,600,000
Average rate base					$ 878,000,000
Weighted average cost of capital (after-tax) (percent)					6.97%
Actual return on common equity (percent)					9.60%
Cost of long-term debt (percent)					5.17%
Requested rate increase (decrease), amount					$ 8,600,000
Deferral, annual maximum (not more than) (percent)					10.00%
O&R | Electric | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 48,000,000
O&R | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,400,000
O&R | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 4,900,000
Amortization to income of net regulatory assets				11,800,000
Potential earnings adjustment mechanism incentives				3,300,000
Net utility plant reconciliations				1,175,000,000
Average rate base				$ 1,021,000,000
Weighted average cost of capital (after-tax) (percent)				6.77%
Cost of long-term debt (percent)				4.58%
Requested rate increase (decrease), amount				$ 11,700,000
O&R | Electric | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				4,300,000
O&R | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes					8,000,000
Amortization to income of net regulatory assets					1,500,000
Potential earnings adjustment mechanism incentives					4,000,000
Average rate base					$ 906,000,000
Weighted average cost of capital (after-tax) (percent)					6.96%
Actual return on common equity (percent)					8.76%
Cost of long-term debt (percent)					5.14%
Requested rate increase (decrease), amount					$ 12,100,000
Deferral, annual maximum (not more than) (percent)					7.50%
O&R | Electric | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 58,000,000
O&R | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					4,400,000
O&R | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				16,200,000
Amortization to income of net regulatory assets				13,500,000
Potential earnings adjustment mechanism incentives				2,300,000
Net utility plant reconciliations				1,198,000,000
Average rate base				$ 1,044,000,000
Weighted average cost of capital (after-tax) (percent)				6.73%
Cost of long-term debt (percent)				4.51%
Requested rate increase (decrease), amount				$ 11,700,000
O&R | Electric | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				4,400,000
O&R | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes					5,800,000
Amortization to income of net regulatory assets					1,500,000
Potential earnings adjustment mechanism incentives					4,200,000
Average rate base					$ 948,000,000
Weighted average cost of capital (after-tax) (percent)					6.96%
Actual return on common equity (percent)					9.16%
Cost of long-term debt (percent)					5.14%
Requested rate increase (decrease), amount					$ 12,200,000
Deferral, annual maximum (not more than) (percent)					5.00%
O&R | Electric | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 61,000,000
O&R | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)					$ 4,500,000
O&R | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes				23,100,000
Amortization to income of net regulatory assets				15,200,000
Potential earnings adjustment mechanism incentives				4,000,000
Net utility plant reconciliations				1,304,000,000
Average rate base				$ 1,144,000,000
Weighted average cost of capital (after-tax) (percent)				6.72%
Cost of long-term debt (percent)				4.49%
Requested rate increase (decrease), amount				$ 11,700,000
O&R | Electric | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				$ 5,100,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	$ 500,000
Energy Efficiency | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	1,800,000	1,900,000	2,600,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	200,000	300,000	700,000
Incentives reversed	300,000
Service Termination | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives	0	$ 500,000	$ 200,000
Incentives reversed	$ 500,000

Regulatory Matters - Summary _6

Regulatory Matters - Summary of Utilities Rate Plans (RECO) (Details) - RECO - USD ($) $ in Thousands	Mar. 30, 2022	Jan. 01, 2022	Jan. 31, 2022	Dec. 31, 2016	Dec. 31, 2021	Jan. 31, 2020	Jan. 31, 2016
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization						$ 200
Regulatory liabilities, amortization period						3 years
Amortization to income of net regulatory assets					$ 4,800	$ 25,600
Regulatory assets, amortization period					4 years	4 years
Average rate base					$ 229,900	$ 178,700
Weighted average cost of capital (after-tax) (percent)					7.11%	7.47%
Authorized return on common equity (percent)					9.50%	9.60%
Cost of long-term debt (percent)					4.88%	5.37%
Common equity ratio, percentage					48.32%	49.70%
Electric
Public Utilities, General Disclosures [Line Items]
Plan electric system storm hardening amount							$ 15,700
Plan period (years)				3 years
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 12,000	$ 1,700
Actual return on common equity (percent)					5.40%	7.50%
Year 2
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)					2.30%	5.70%
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities, amortization period		3 years
Amortization to income of net regulatory assets		$ 9,200
Regulatory assets, amortization period		3 years
Average rate base		$ 262,800
Weighted average cost of capital (after-tax) (percent)			7.08%
Authorized return on common equity (percent)			9.60%
Cost of long-term debt (percent)			4.74%
Common equity ratio, percentage			48.51%
Scenario, Forecast | Tropical Storm Henri
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory assets		$ 2,400
Regulatory assets, amortization period		3 years
Scenario, Forecast | Electric
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 20,400	$ 16,900
Return on common equity (percent)		11.04%
Common equity ratio		47.00%
Scenario, Forecast | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes			$ 9,650
Scenario, Forecast | Period 1
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization		$ 200
Regulatory liabilities, amortization period		3 years
Scenario, Forecast | Period 2
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization		$ 10,000

Regulatory Matters - COVID-19 R

Regulatory Matters - COVID-19 Regulatory Matters (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended			13 Months Ended		22 Months Ended
	Jan. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Jan. 01, 2021
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		$ 169,000	$ 78,000	$ 8,000
CECONY
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		166,000	$ 74,000	$ 7,000
COVID-19
Public Utilities, General Disclosures [Line Items]
Deferred costs		900					$ 900
COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		239,000
Allowance for credit loss, write-off							8,000
COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve for customer arrearages		7,000					7,000
COVID-19 | CECONY | Electric | Subsidiaries | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees					$ 19,000	$ 43,000
COVID-19 | CECONY | Gas | Subsidiaries | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Late payment charges and fees					$ 4,000	$ 7,000
COVID-19 | O&R
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		7,000
Allowance for credit loss, write-off							3,000
Residential Customers | COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Deferred revenue		$ 54,900					$ 54,900
Summer Cooling Credit Program | Residential Customers | COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Expected deferred revenue								$ 63,400
Cost of the program, recovery period	5 years

Regulatory Matters - Other Regu

Regulatory Matters - Other Regulatory Matters (Details) customer in Thousands, $ in Millions

Jan. 01, 2022USD ($)

Jul. 31, 2021USD ($)

Jan. 31, 2021USD ($)

Nov. 30, 2020USD ($)claim

Aug. 31, 2020USD ($)customer

Jul. 31, 2019USD ($)customer

Jun. 30, 2021USD ($)

Sep. 30, 2018USD ($)

Dec. 31, 2021USD ($)

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Dec. 31, 2022USD ($)

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

$ 4,381

$ 4,513

Other customer-provided capital rate

1.80%

2.65%

Return on regulatory assets

$ 1,962

$ 1,639

Net unbilled revenue deferrals

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

209

198

RECO

Public Utilities, General Disclosures [Line Items]

Return on regulatory assets

25

31

RECO | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Restoration costs

11.4

Operation and maintenance expenses charged against a storm reserve

7.6

Capital expenditures

$ 2.5

Food and medicine spoilage expense

$ 1.3

CECONY

Public Utilities, General Disclosures [Line Items]

Net regulatory assets

1,176

1,200

Regulatory liabilities

3,921

4,094

Return on regulatory assets

$ 1,751

1,454

CECONY | Commodity

Public Utilities, General Disclosures [Line Items]

Regulatory assets, recovery period

4 years

CECONY | Net unbilled revenue deferrals

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

$ 209

198

CECONY | Electric | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 377

CECONY | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

330

Litigation settlement, amount awarded to other party

$ 75.1

Litigation settlement, period

35 years

Estimate of possible loss

$ 102.3

Restoration costs

$ 174

Operation and maintenance expenses charged against a storm reserve

84

Capital expenditures

64

Operation and maintenance expenses

26

Food and medicine spoilage expense

$ 7.5

Alleged number of claims, violations | claim

33

CECONY | Electric | Protected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

1,663

CECONY | Electric | Unprotected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

784

CECONY | Electric | Scenario, Forecast | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

3 years

CECONY | Electric | Scenario, Forecast | Protected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 1,663

CECONY | Electric | Scenario, Forecast | Unprotected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 784

CECONY | Electric | Scenario, Forecast | Unprotected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

5 years

CECONY | Gas | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

63

CECONY | Gas | Protected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

725

CECONY | Gas | Unprotected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 107

CECONY | Gas | Scenario, Forecast | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

2 years

CECONY | Gas | Scenario, Forecast | Protected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 725

CECONY | Gas | Scenario, Forecast | Unprotected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

5 years

CECONY | NYSPSC | Steam | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 185

O&R

Public Utilities, General Disclosures [Line Items]

Net regulatory assets

$ 26

$ 29

O&R | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

200

Litigation settlement, amount awarded to other party

$ 7

Property damage, clean up and response costs

$ 1.6

Estimate of possible loss

$ 19

Restoration costs

26.5

Operation and maintenance expenses charged against a storm reserve

19.2

Capital expenditures

$ 5.7

Alleged number of claims, violations | claim

38

O&R | Electric and Gas | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 22

O&R | Electric and Gas | Protected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 123

O&R | Electric and Gas | Scenario, Forecast | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

3 years

O&R | Electric and Gas | Scenario, Forecast | Unprotected Portion | Subsidiaries

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

6 years

Increase in regulatory liability resulting from TCJA

$ 34

Manhattan | CECONY | Electric | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

190

72

Estimate of possible loss

$ 24.8

Brooklyn | CECONY | Electric

Public Utilities, General Disclosures [Line Items]

Cumulative catch-up adjustment to revenue, modification of contract

$ (15)

Brooklyn | CECONY | Electric | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

30

Foregone Customer Recovery | CECONY | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

25

Foregone Customer Recovery | O&R | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

2.5

Ongoing Operations And Maintenance Costs | CECONY | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

15.8

Ongoing Operations And Maintenance Costs | O&R | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

2.9

Previously Incurred Or Accrued Costs | CECONY | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

34.3

Previously Incurred Or Accrued Costs | O&R | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

1.6

Negative Revenue Adjustment | CECONY | Electric | Rainey Outages | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

5

Negative Revenue Adjustment | CECONY | Electric | 2019 Manhattan and Brooklyn Outages | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

15

Costs To Reimburse Customers For Food And Medicine Spoilage | CECONY | Electric | Tropical Storm | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Litigation settlement, amount awarded to other party

$ 14.3

Manhattan Steam Main Rupture | CECONY | NYSPSC | Subsidiaries

Public Utilities, General Disclosures [Line Items]

Property damage, clean up and response costs

$ 17

Capital and retirement costs

9

Loss contingency accrual

$ 3

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 3,639	$ 6,195
Regulatory assets – current	206	266
Total Regulatory Assets	3,845	6,461
Regulatory assets not earning return	1,883	4,823
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	128	3,241
Regulatory assets not earning return	128	3,241
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	938	865
Regulatory assets not earning return	928	855
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	395	356
Regulatory assets not earning return	375	336
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	496	315
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	202	241
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	276	195
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	140	188
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	285	124
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	51	120
Regulatory assets not earning return	51	120
COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	282	115
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	44	62
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	36
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	29	32
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	25
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	16	21
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	16	20
Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	18
COVID-19 Deferral for Uncollectible Accounts Receivable
Regulatory Assets [Line Items]
Regulatory assets not earning return	236	57
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	248	200
Regulatory assets not earning return	24	24
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	141	190
Regulatory assets not earning return	141	190
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	65	76
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,316	5,745
Regulatory assets – current	188	244
Total Regulatory Assets	3,504	5,989
Regulatory assets not earning return	1,753	4,536
CECONY | Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	110	3,065
Regulatory assets not earning return	110	3,065
CECONY | Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	860	791
Regulatory assets not earning return	850	781
CECONY | Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	378	342
Regulatory assets not earning return	359	323
CECONY | Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	435	272
CECONY | Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	202	239
CECONY | Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	158	83
CECONY | MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	140	188
CECONY | System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	284	124
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	45	111
Regulatory assets not earning return	45	111
CECONY | COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	277	113
CECONY | Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	44	62
CECONY | Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	36
CECONY | Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	29	32
CECONY | Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	25
CECONY | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	19
CECONY | Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
CECONY | Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	18
CECONY | Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	18
CECONY | COVID-19 Deferral for Uncollectible Accounts Receivable
Regulatory Assets [Line Items]
Regulatory assets not earning return	231	55
CECONY | Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	232	186
Regulatory assets not earning return	24	24
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	133	177
Regulatory assets not earning return	134	177
CECONY | Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	$ 55	$ 67

Regulatory Matters - Regulato_2

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 4,381	$ 4,513
Regulatory liabilities—current	185	36
Total Regulatory Liabilities	4,566	4,549
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,984	2,207
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,199	1,090
TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	125	295
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	209	198
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	103	137
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	102	85
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	70	64
Deferred derivative gains - long term
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	61	5
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	36
BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	25	27
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	21
Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	17	16
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	13	15
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	32	11
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	5
Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	8	3
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	1
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	365	297
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	32	28
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	142	8
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	11	0
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3,921	4,094
Regulatory liabilities—current	134	11
Total Regulatory Liabilities	4,055	4,105
CECONY | Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,840	2,062
CECONY | Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,033	932
CECONY | TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	123	286
CECONY | Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	209	198
CECONY | Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	103	137
CECONY | Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	55	46
CECONY | System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	63	57
CECONY | Deferred derivative gains - long term
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	55	4
CECONY | Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	35
CECONY | BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	22	25
CECONY | Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	21
CECONY | Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	16
CECONY | Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	10
CECONY | Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	0
CECONY | Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	5
CECONY | Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	8	3
CECONY | Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	19	0
CECONY | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	312	257
CECONY | Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	2	4
CECONY | Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	132	7
CECONY | Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	$ 0	$ 0

Capitalization - Common Stock (

Capitalization - Common Stock (Details) - USD ($) $ in Millions	1 Months Ended
	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)		500,000,000
Common stock, shares outstanding (in shares)		353,983,712	342,297,534
Treasury shares (in shares)		23,210,700	23,210,700
Shares issued (in shares)	10,100,000
Proceeds from issuance of equity	$ 775
CECONY
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)		340,000,000
Common stock, shares outstanding (in shares)		235,488,094	235,488,094
Treasury shares (in shares)		21,976,200	21,976,200

Capitalization - Dividends (Det

Capitalization - Dividends (Details)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Percentage limitation for income available for dividends (not more than)	100.00%
Rolling average calculation of income available for dividends (years)	2 years

Capitalization - Schedule of Lo

Capitalization - Schedule of Long-Term Debt Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
2022	$ 440
2023	969
2024	393
2025	319
2026	385
Long-term debt	23,044	$ 22,349
Long-term debt due within one year		1,967
CECONY
Debt Instrument [Line Items]
2022	0
2023	0
2024	250
2025	0
2026	250
Long-term debt	$ 18,382	16,789
Long-term debt due within one year		$ 640

Capitalization - Long-term Debt

Capitalization - Long-term Debt, Additional Information (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Long-term debt	$ 23,044,000,000	$ 22,349,000,000
CECONY
Debt Instrument [Line Items]
Long-term debt	18,382,000,000	16,789,000,000
CECONY | Tax-Exempt Debt
Debt Instrument [Line Items]
Debt instrument, face amount	450,000,000
Long-term debt	$ 450,000,000	$ 450,000,000

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Unamortized debt expense	$ 226	$ 215
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	23,044	22,349
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	26,287	26,808
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	193	176
CECONY | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	18,382	16,789
CECONY | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 21,382	$ 20,974

Capitalization - Significant De

Capitalization - Significant Debt Covenants (Details)	12 Months Ended
	Dec. 31, 2021USD ($)
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.52
Covenant principal balance amount limit	$ 100,000,000
CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.55
Tax-Exempt Debt | CECONY
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Term Loan | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 150,000,000
Notes
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.675
Notes | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 100,000,000

Short-Term Borrowing (Details)

Short-Term Borrowing (Details)	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,488,000,000	$ 1,705,000,000
Weighted average interest rate	0.30%	0.30%
Loans outstanding under credit agreement	$ 0	$ 0
Maximum ratio of consolidated debt to consolidated total capital	0.52
Minimum percentage of liens on assets	5.00%
Failure to pay, maximum aggregate limit	$ 150,000,000
Maximum
Short-term Debt [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 1,500,000,000
Current amount available	1,000,000,000
Letters of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	1,200,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,361,000,000	$ 1,660,000,000
Weighted average interest rate	0.30%	0.30%
Maximum ratio of consolidated debt to consolidated total capital	0.55
Credit Availability Through December 2022 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 2,250,000,000
Credit Availability Through December 2023 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 2,200,000,000

Pension Benefits - Total Period

Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 343	$ 293	$ 250
Interest cost on projected benefit obligation	471	549	601
Expected return on plan assets	(1,096)	(1,034)	(988)
Recognition of net actuarial loss	787	699	518
Recognition of prior service credit	(17)	(16)	(17)
TOTAL PERIODIC BENEFIT COST	488	491	364
Cost capitalized	(154)	(130)	(108)
Reconciliation to rate level	(226)	(250)	(15)
Total credit recognized	108	111	241
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	321	274	232
Interest cost on projected benefit obligation	443	515	564
Expected return on plan assets	(1,040)	(980)	(936)
Recognition of net actuarial loss	746	661	492
Recognition of prior service credit	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	451	451	333
Cost capitalized	(146)	(123)	(102)
Reconciliation to rate level	(216)	(239)	(12)
Total credit recognized	$ 89	$ 89	$ 219

Pension Benefits - Schedule of

Pension Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 465
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	525	$ 465
Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	18,965	16,792	$ 14,449
Service cost – excluding administrative expenses	337	288	245
Interest cost on projected benefit obligation	471	549	601
Net actuarial loss/(gain)	(1,547)	2,281	2,191
Plan amendments	0	0	15
Benefits paid	(869)	(945)	(709)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	17,357	18,965	16,792
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	17,022	15,608	13,450
Actual return on plan assets	1,935	1,927	2,556
Employer contributions	469	475	350
Benefits paid	(869)	(945)	(709)
Administrative expenses	(53)	(43)	(39)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	18,504	17,022	15,608
FUNDED STATUS	1,147	(1,943)	(1,184)
Unrecognized net loss	205	3,330	2,604
Unrecognized prior service costs/(credits)	(140)	(156)	(173)
Accumulated benefit obligation	15,469	16,768	15,015
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	439
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	499	439
CECONY | Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	17,821	15,750	13,542
Service cost – excluding administrative expenses	317	269	228
Interest cost on projected benefit obligation	443	515	564
Net actuarial loss/(gain)	(1,441)	2,154	2,076
Plan amendments	0	0	0
Benefits paid	(799)	(867)	(660)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	16,341	17,821	15,750
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	16,147	14,790	12,744
Actual return on plan assets	1,838	1,830	2,425
Employer contributions	432	435	318
Benefits paid	(799)	(867)	(660)
Administrative expenses	(52)	(41)	(37)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	17,566	16,147	14,790
FUNDED STATUS	1,225	(1,674)	(960)
Unrecognized net loss	207	3,145	2,466
Unrecognized prior service costs/(credits)	(163)	(183)	(202)
Accumulated benefit obligation	$ 14,504	$ 15,676	$ 14,010

Pension Benefits - Additional I

Pension Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 3,090	$ 759
Investments value	525	465
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	3,067
Charge to OCI	30
Noncurrent liabilities	459
Investments value	18,504	17,022	$ 15,608	$ 13,450
Accumulated benefit obligation	15,469	16,768	15,015
Estimated future employer contributions	29
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	386	414
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	2,899	714
Investments value	499	439
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	2,910
Charge to OCI	6
Noncurrent liabilities	381
Investments value	17,566	16,147	14,790	$ 12,744
Accumulated benefit obligation	14,504	15,676	$ 14,010
Estimated future employer contributions	20
CECONY | Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 352	$ 377

Pension Benefits - Schedule o_2

Pension Benefits - Schedule of Assumptions (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CECONY
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.80%	3.80%	3.80%
Rate of compensation increase	3.80%	3.80%	4.25%
O&R
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.20%	3.20%	3.20%
Rate of compensation increase	3.20%	3.20%	4.00%
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	3.00%	2.55%	3.35%
Interest crediting rate for cash balance plan	3.50%	3.00%	3.30%
Discount rate, net periodic benefit cost	2.55%	3.35%	4.25%
Interest crediting rate for cash balance plan	3.00%	3.30%	4.00%
Expected return on plan assets	7.00%	7.00%	7.00%

Pension Benefits - Schedule o_3

Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2021USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 765
2021	782
2022	791
2023	841
2024	818
2027-2031	4,219
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	704
2021	721
2022	730
2023	780
2024	756
2027-2031	$ 3,924

Pension Benefits - Schedule o_4

Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	50.00%	51.00%	51.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	45.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	55.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	38.00%	38.00%	38.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	33.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	43.00%
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	12.00%	11.00%	11.00%
Real Estate | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	10.00%
Real Estate | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	14.00%

Pension Benefits - Schedule o_5

Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 525	$ 465
Private Equity
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	Fair Value Measured at Net Asset Value Per Share	Fair Value Measured at Net Asset Value Per Share
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 18,504	$ 17,022	$ 15,608	$ 13,450
Pension Benefits | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,381	4,202
Pension Benefits | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,536	3,693
Pension Benefits | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,500	1,424
Pension Benefits | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,936	3,535
Pension Benefits | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	262	188
Pension Benefits | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,186	1,067
Pension Benefits | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	505	459
Pension Benefits | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2
Pension Benefits | Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	913	635
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,306	1,880
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	315	292
Pension Benefits | Total Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(258)	(254)
Pension Benefits | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(80)	(99)
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	15,308	14,568
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(210)	(213)
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	18,584	17,121
Pension Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,999	7,946
Pension Benefits | Level 1 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,381	4,202
Pension Benefits | Level 1 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,536	3,693
Pension Benefits | Level 1 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		0
Pension Benefits | Level 1 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	80	51
Pension Benefits | Level 1 | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2
Pension Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(110)	(116)
Pension Benefits | Level 1 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,889	7,830
Pension Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,309	6,622
Pension Benefits | Level 2 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 2 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,500	1,424
Pension Benefits | Level 2 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,936	3,535
Pension Benefits | Level 2 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	262	188
Pension Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,186	1,067
Pension Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	425	408
Pension Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(100)	(97)
Pension Benefits | Level 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,209	6,525
Pension Benefits | Fair Value Measured at Net Asset Value Per Share | Investments Valued Using NAV Per Share
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,534	2,807
Pension Benefits | Fair Value Measured at Net Asset Value Per Share | Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ (48)	$ (41)

Pension Benefits - Schedule o_6

Pension Benefits - Schedule of Employer Contribution to Defined Savings Plan (Details) - Defined Contribution Savings Plan - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 55	$ 52	$ 49
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 46	$ 43	$ 42

Other Postretirement Benefits -

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 22	$ 21	$ 18
Interest cost on accumulated other postretirement benefit obligation	33	37	44
Expected return on plan assets	(68)	(66)	(66)
Recognition of net actuarial loss/(gain)	31	37	(9)
Recognition of prior service credit	(3)	(3)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	15	26	(15)
Cost capitalized	(9)	(9)	(7)
Reconciliation to rate level	(7)	(17)	12
Total credit recognized	(1)	0	(10)
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	16	16	13
Interest cost on accumulated other postretirement benefit obligation	28	31	36
Expected return on plan assets	(56)	(54)	(54)
Recognition of net actuarial loss/(gain)	27	36	(10)
Recognition of prior service credit	(1)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	14	27	(17)
Cost capitalized	(7)	(7)	(5)
Reconciliation to rate level	(12)	(25)	7
Total credit recognized	$ (5)	$ (5)	$ (15)

Other Postretirement Benefits_2

Other Postretirement Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 465
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	525	$ 465
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	439
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	499	439
Other Postretirement Benefits
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,425	1,357	$ 1,114
Service cost	22	21	18
Interest cost on accumulated other postretirement benefit obligation	33	37	44
Amendments	0	0	(14)
Net actuarial loss/(gain)	(13)	74	264
Benefits paid and administrative expenses, net of subsidies	(117)	(117)	(110)
Participant contributions	48	53	41
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,398	1,425	1,357
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	1,115	1,026	885
Actual return on plan assets	92	142	198
Employer contributions	6	7	7
Employer group waiver plan subsidies	21	20	23
Participant contributions	48	53	40
Benefits paid	(132)	(133)	(127)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,150	1,115	1,026
FUNDED STATUS	(248)	(310)	(331)
Unrecognized net loss/(gain)	41	115	155
Unrecognized prior service costs	(13)	(16)	(19)
Other Postretirement Benefits | CECONY
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,209	1,154	913
Service cost	16	16	13
Interest cost on accumulated other postretirement benefit obligation	28	31	36
Amendments	0	0	0
Net actuarial loss/(gain)	(3)	63	252
Benefits paid and administrative expenses, net of subsidies	(107)	(107)	(100)
Participant contributions	46	52	40
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,189	1,209	1,154
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	940	872	759
Actual return on plan assets	67	117	165
Employer contributions	3	4	6
Employer group waiver plan subsidies	19	19	22
Participant contributions	46	51	40
Benefits paid	(120)	(123)	(120)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	955	940	872
FUNDED STATUS	(234)	(269)	(282)
Unrecognized net loss/(gain)	67	114	149
Unrecognized prior service costs	$ 0	$ (1)	$ (3)

Other Postretirement Benefits_3

Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	$ (62)	$ 21
Noncurrent liabilities	79
Increase (decrease) in regulatory liabilities	67
Expected contributions	8
CECONY
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	(35)	$ 13
Noncurrent liabilities	55
Increase (decrease) in regulatory liabilities	$ 46

Other Postretirement Benefits_4

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Details) - Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected Return on Plan Assets	6.80%	6.80%	6.80%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	2.75%	2.25%	3.10%
Discount Rate, Net Periodic Benefit Cost	2.25%	3.10%	4.15%
O&R
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	3.00%	2.55%	3.35%
Discount Rate, Net Periodic Benefit Cost	2.55%	3.35%	4.30%

Other Postretirement Benefits_5

Other Postretirement Benefits - Schedule of Change of Assumed Health Care Cost Trend Rate (Details) - Other Postretirement Benefits	Dec. 31, 2021
Pre-65 Medical
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	6.80%
Ultimate Cost Trend Rate	4.50%
Post-65 Medical
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	4.50%
Ultimate Cost Trend Rate	4.50%
Prescription Medications
Defined Benefit Plan Disclosure [Line Items]
Initial Cost Trend Rate	7.25%
Ultimate Cost Trend Rate	4.50%

Other Postretirement Benefits_6

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Details) - Other Postretirement Benefits $ in Millions	Dec. 31, 2021USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 75
2021	77
2022	77
2023	78
2024	78
2027-2031	385
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	84
2021	86
2022	86
2023	87
2024	88
2027-2031	$ 435

Other Postretirement Benefits_7

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Details) - Other Postretirement Benefits - CECONY	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	55.00%	54.00%	54.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	42.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	80.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	45.00%	46.00%	46.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	20.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	58.00%

Other Postretirement Benefits_8

Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 525	$ 465
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,150	1,115	$ 1,026	$ 885
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	875	842
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	474	448
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	379	367
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	22	27
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	210	213
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,085	1,055
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	48	41
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	17	19
Other Postretirement Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	110	116
Other Postretirement Benefits | Level 1 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	110	116
Other Postretirement Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	875	842
Other Postretirement Benefits | Level 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	474	448
Other Postretirement Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	379	367
Other Postretirement Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	22	27
Other Postretirement Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	100	97
Other Postretirement Benefits | Level 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 975	$ 939

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Site Contingency [Line Items]
Accrued Liabilities	$ 940	$ 857
Regulatory assets	3,845	6,461
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	845	752
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	95	105
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	940	857
Regulatory assets	938	865
CECONY
Site Contingency [Line Items]
Accrued Liabilities	850	780
Regulatory assets	3,504	5,989
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	755	676
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	95	104
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	850	780
Regulatory assets	$ 860	$ 791

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 25	$ 33
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 24	$ 32

Environmental Matters - Additio

Environmental Matters - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
Superfund Sites
Site Contingency [Line Items]
Remediation cost estimate	$ 40
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	2,980
Superfund Sites | CECONY
Site Contingency [Line Items]
Remediation cost estimate	38
Superfund Sites | CECONY | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,840

Environmental Matters - Accru_2

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Site Contingency [Line Items]
Regulatory assets	$ 3,845	$ 6,461
Regulatory liabilities	4,566	4,549
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	65	72
Regulatory liabilities	8	3
CECONY
Site Contingency [Line Items]
Regulatory assets	3,504	5,989
Regulatory liabilities	4,055	4,105
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers' Compensation
Site Contingency [Line Items]
Accrued liability	62	68
Regulatory liabilities	$ 8	$ 3

Material Contingencies - Manhat

Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions	Mar. 12, 2014peoplebuilding	Feb. 28, 2017USD ($)	Dec. 31, 2021USD ($)lawsuit	Dec. 31, 2020USD ($)	Oct. 31, 2020USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 4,381	$ 4,513
Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 12	$ 21
Manhattan Explosion and Fire
Loss Contingencies [Line Items]
Number of buildings destroyed by fire | building	2
Number of people died in explosion and fire incident | people	8
Number of people injured in explosion and fire incident (more than) | people	50
Amount of costs that will not recover from customers		$ 126
Number of pending lawsuits | lawsuit			80
Loss contingency accrual					$ 40
Manhattan Explosion and Fire | Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

Material Contingencies - Guaran

Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Guarantee obligations maximum exposure	$ 2,157	$ 2,042

Material Contingencies - Total

Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,157	$ 2,042
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	490
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	831
Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	766
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,348
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	490
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	469
0 – 3 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	319
0 – 3 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	88
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	37
4 – 10 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	51
4 – 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	721
> 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	325
> 10 years | Renewable electric projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	396
> 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

Material Contingencies - Con Ed

Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,157	$ 2,042
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Estimated project cost percentage	175.00%
Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 490
NY Transco | Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage	45.70%

Material Contingencies - Other

Material Contingencies - Other (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,157	$ 2,042
Financial Guarantee for Indemnity Agreements for Surety Bonds in Connection with Operation of Solar Energy Facilities and Energy Service Projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 70

Electricity Purchase Agreemen_3

Electricity Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2021USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2022	$ 126
2023	78
2024	55
2025	55
2026	56
All Years Thereafter	434
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2022	124
2023	78
2024	55
2025	55
2026	56
All Years Thereafter	$ 434

Electricity Purchase Agreemen_4

Electricity Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 159	$ 139	$ 231
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	20	26	116
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 139	$ 113	$ 115

Leases - Additional Information

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Lease, renewal term	5 years
Assets under finance leases	$ 2	$ 3
Finance leases, accumulated amortization	4	3
Right-of-use asset obtained in exchange for operating lease liability	$ 58	23
Lease not yet commenced, term	45 years
Lease not yet commenced, present value of lease payments	$ 6
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	1	2
Finance leases, accumulated amortization	2	1
Right-of-use asset obtained in exchange for operating lease liability	$ 12	$ 11
Minimum
Lessee, Lease, Description [Line Items]
Lease, term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease, term	40 years

Leases - Lease Cost and Cash Fl

Leases - Lease Cost and Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 86	$ 85
Operating lease cash flows	80	79
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	66	65
Operating lease cash flows	$ 63	$ 61

Leases - Other Related Informat

Leases - Other Related Information (Details)	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	18 years 6 months	19 years 1 month 6 days
Weighted Average Remaining Lease Term, Finance leases	7 years 1 month 6 days	7 years 3 months 18 days
Weighted Average Discount Rate, Operating leases	4.30%	4.30%
Weighted Average Discount Rate, Finance leases	1.80%	1.80%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	12 years 1 month 6 days	13 years
Weighted Average Remaining Lease Term, Finance leases	3 years 1 month 6 days	4 years
Weighted Average Discount Rate, Operating leases	3.50%	3.60%
Weighted Average Discount Rate, Finance leases	1.10%	1.30%

Leases - Future Minimum Lease P

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Operating Leases
2022	$ 81
2023	77
2024	77
2025	78
2026	76
All years thereafter	877
Total future minimum lease payments	1,266
Less: imputed interest	(436)
Total	830
Operating lease liabilities (current)	113	$ 96
Operating lease liabilities (noncurrent)	717	$ 764
Total	830
Finance Leases
2022	0
2023	0
2024	1
2025	0
2026	0
All years thereafter	1
Total future minimum lease payments	2
Less: imputed interest	0
Total	2
Other current liabilities	0
Other noncurrent liabilities	2
Total	$ 2
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Liabilities, Current	Liabilities, Current
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Liabilities, Other than Long-term Debt, Noncurrent	Liabilities, Other than Long-term Debt, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Liabilities, Other than Long-term Debt, Noncurrent, Other Liabilities	Liabilities, Other than Long-term Debt, Noncurrent, Other Liabilities
CECONY
Operating Leases
2022	$ 60
2023	59
2024	59
2025	60
2026	59
All years thereafter	394
Total future minimum lease payments	691
Less: imputed interest	(139)
Total	552
Operating lease liabilities (current)	90	$ 73
Operating lease liabilities (noncurrent)	462	$ 512
Total	552
Finance Leases
2022	0
2023	0
2024	1
2025	0
2026	0
All years thereafter	0
Total future minimum lease payments	1
Less: imputed interest	0
Total	1
Other current liabilities	0
Other noncurrent liabilities	1
Total	$ 1

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Goodwill [Line Items]
Goodwill	$ 439	$ 446
Goodwill impaired	7
CECONY
Goodwill [Line Items]
Goodwill	245	245
Goodwill impaired	2
O&R
Goodwill [Line Items]
Goodwill	161	161
CET Gas
Goodwill [Line Items]
Goodwill impaired	5
O&R Merger
Goodwill [Line Items]
Goodwill	406	406
Gas Storage Company | CET Gas
Goodwill [Line Items]
Goodwill	8	8
Residential Solar Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	14	14
Battery Storage Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	$ 18	$ 18

Income Tax - Schedule of Compon

Income Tax - Schedule of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
State
Current	$ 14	$ 7	$ (12)
Deferred	79	50	96
Federal
Current	43	(2)	0
Deferred	61	42	219
Amortization of investment tax credits	(7)	(7)	(7)
Total income tax expense	190	90	296
CECONY
State
Current	1	6	22
Deferred	106	97	68
Federal
Current	121	41	185
Deferred	21	73	63
Amortization of investment tax credits	(3)	(2)	(3)
Total income tax expense	$ 246	$ 215	$ 335

Income Tax - Schedule of Differ

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred tax liabilities:
Property basis differences	$ 8,298	$ 7,985
Regulatory assets:
Unrecognized pension and other postretirement costs	36	910
Environmental remediation costs	264	243
Deferred storm costs	33	31
Other regulatory assets	640	536
Operating lease right-of-use asset	204	220
Pension Asset Reserve	478	0
Equity investments	0	46
Other	30	0
Total deferred tax liabilities	9,983	9,971
Deferred tax assets:
Accrued pension and other postretirement costs	218	504
Future income tax	554	617
Other regulatory liabilities	727	656
Superfund and other environmental costs	264	241
Asset retirement obligations	177	178
Operating lease liabilities	195	211
Loss carryforwards	144	164
Tax credits carryforward	946	1,022
Valuation allowance	(22)	(22)
Equity investments	34	0
Other	0	59
Total deferred tax assets	3,237	3,630
Net deferred tax liabilities	6,746	6,341
Unamortized investment tax credits	127	134
Net deferred tax liabilities and unamortized investment tax credits	6,873	6,475
CECONY
Deferred tax liabilities:
Property basis differences	7,213	6,901
Regulatory assets:
Unrecognized pension and other postretirement costs	31	861
Environmental remediation costs	241	222
Deferred storm costs	0	0
Other regulatory assets	609	508
Operating lease right-of-use asset	155	165
Pension Asset Reserve	471	0
Equity investments	0	0
Other	0	0
Total deferred tax liabilities	8,720	8,657
Deferred tax assets:
Accrued pension and other postretirement costs	188	427
Future income tax	517	579
Other regulatory liabilities	620	570
Superfund and other environmental costs	238	219
Asset retirement obligations	141	143
Operating lease liabilities	155	165
Loss carryforwards	38	34
Tax credits carryforward	0	0
Valuation allowance	0	0
Equity investments	0	0
Other	42	127
Total deferred tax assets	1,939	2,264
Net deferred tax liabilities	6,781	6,393
Unamortized investment tax credits	15	18
Net deferred tax liabilities and unamortized investment tax credits	$ 6,796	$ 6,411

Income Tax - Additional Informa

Income Tax - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Operating Loss Carryforwards [Line Items]
Unrecognized tax benefits	$ 17	$ 14	$ 13	$ 6
Effective income tax rate reconciliation, uncertainty of taxes	12
Unrecognized tax benefits that would have an impact on effective tax rate	17
Unrecognized tax benefits that would have an impact on effective tax rate, net of tax	16
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Tax credit carryovers	946
Tax Year 2018 Through 2013
Operating Loss Carryforwards [Line Items]
Operating loss carryback	29
Net tax refund		2.5
Tax Year 2013
Operating Loss Carryforwards [Line Items]
Discrete income tax benefit		4
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards, valuation allowance	21.5
State | New York State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	1,130
State | New York City
Operating Loss Carryforwards [Line Items]
Valuation allowance reversed	5
Deferred tax assets	17
CECONY
Operating Loss Carryforwards [Line Items]
Unrecognized tax benefits	5	$ 3	$ 2	$ 4
Effective income tax rate reconciliation, uncertainty of taxes	3
Unrecognized tax benefits that would have an impact on effective tax rate	$ 5

Income Tax - Schedule of Income

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4.00%	4.00%	4.00%
Taxes attributable to noncontrolling interests	3.00%	(1.00%)	(1.00%)
Cost of removal	2.00%	2.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
Amortization of excess deferred federal income taxes	(12.00%)	(14.00%)	(4.00%)
Renewable energy credits	(2.00%)	(3.00%)	(2.00%)
Research and development credits	(1.00%)	0.00%	(1.00%)
Other	0.00%	(1.00%)	0.00%
Effective tax rate	14.00%	7.00%	17.00%
CECONY
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	5.00%	5.00%	5.00%
Taxes attributable to noncontrolling interests	0.00%	0.00%	0.00%
Cost of removal	1.00%	1.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
Amortization of excess deferred federal income taxes	(11.00%)	(12.00%)	(4.00%)
Renewable energy credits	0.00%	0.00%	0.00%
Research and development credits	0.00%	0.00%	(1.00%)
Other	0.00%	1.00%	0.00%
Effective tax rate	15.00%	15.00%	21.00%

Income Tax - Summary of Unrecog

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 14	$ 13	$ 6
Additions based on tax positions related to the current year	3	0	1
Additions based on tax positions of prior years	2	1	10
Reductions for tax positions of prior years	(2)	0	(2)
Reductions from expiration of statute of limitations	0	0	0
Settlements	0	0	(2)
Balance at end of period	17	14	13
CECONY
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	3	2	4
Additions based on tax positions related to the current year	2	0	1
Additions based on tax positions of prior years	1	1	0
Reductions for tax positions of prior years	(1)	0	(1)
Reductions from expiration of statute of limitations	0	0	0
Settlements	0	0	(2)
Balance at end of period	$ 5	$ 3	$ 2

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 13,456	$ 12,026	$ 12,144
Revenues	13,676	12,246	12,574
Other
Disaggregation of Revenue [Line Items]
Revenues	220	220	430
CECONY
Disaggregation of Revenue [Line Items]
Revenues	11,716	10,647	10,821
CECONY | Decoupling Mechanisms
Disaggregation of Revenue [Line Items]
Revenues	48
CECONY | EAMs
Disaggregation of Revenue [Line Items]
Revenues	34
CECONY | LPCs
Disaggregation of Revenue [Line Items]
Revenues	74
O&R | Decoupling Mechanisms
Disaggregation of Revenue [Line Items]
Revenues	(18)
O&R | EAMs
Disaggregation of Revenue [Line Items]
Revenues	2
O&R | LPCs
Disaggregation of Revenue [Line Items]
Revenues	4
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	917	661	646
Revenues	1,022	736	857
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues	105	75	211
Operating Segments | Clean Energy Businesses | Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	683	609	575
Revenues	683	609	575
Operating Segments | Clean Energy Businesses | Renewables | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Energy services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	234	52	71
Revenues	234	52	71
Operating Segments | Clean Energy Businesses | Energy services | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	105	75	211
Operating Segments | Clean Energy Businesses | Other | Other
Disaggregation of Revenue [Line Items]
Revenues	105	75	211
Operating Segments | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	4	4
Revenues	4	4	4
Operating Segments | Con Edison Transmission | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | CECONY
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11,579	10,518	10,620
Revenues	11,716	10,647	10,821
Operating Segments | CECONY | Other
Disaggregation of Revenue [Line Items]
Revenues	137	129	201
Operating Segments | CECONY | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,736	8,026	7,913
Revenues	8,806	8,103	8,062
Operating Segments | CECONY | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	70	77	149
Operating Segments | CECONY | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,324	1,998	2,097
Revenues	2,378	2,036	2,132
Operating Segments | CECONY | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	54	38	35
Operating Segments | CECONY | Steam
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	519	494	610
Revenues	532	508	627
Operating Segments | CECONY | Steam | Other
Disaggregation of Revenue [Line Items]
Revenues	13	14	17
Operating Segments | O&R
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	956	843	874
Revenues	941	862	893
Operating Segments | O&R | Other
Disaggregation of Revenue [Line Items]
Revenues	(15)	19	19
Operating Segments | O&R | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	691	619	627
Revenues	681	629	634
Operating Segments | O&R | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	(10)	10	7
Operating Segments | O&R | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	265	224	247
Revenues	260	233	259
Operating Segments | O&R | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	(5)	9	12
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	(7)	(3)	(1)
Other | Other
Disaggregation of Revenue [Line Items]
Revenues	(7)	(3)	(1)
Other | O&R
Disaggregation of Revenue [Line Items]
Revenues	$ 0	$ 0	$ 0

Revenue Recognition - Change in

Revenue Recognition - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Unbilled contract revenue
Beginning balance	$ 11	$ 29	$ 29
Additions	242	88	86
Subtractions	218	106	86
Ending balance	35	11	29
Unearned revenue
Beginning balance	41	17	20
Additions	0	31	1
Subtractions	34	7	4
Ending balance	7	41	17
Contracts with customer, revenue recognized, amount outstanding end of last period	$ 34	$ 7	$ 4

Revenue Recognition - Revenue R

Revenue Recognition - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Dec. 31, 2021USD ($)
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 120
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 81
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 39
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction

Revenue Recognition - Additiona

Revenue Recognition - Additional information (Details) - CECONY - NYSPSC - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Electric
Disaggregation of Revenue [Line Items]
Amount of cost recovery	$ 43	$ 19	$ 43
Gas
Disaggregation of Revenue [Line Items]
Amount of cost recovery	$ 7	$ 4	$ 7

Current Expected Credit Losse_2

Current Expected Credit Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 169	$ 78
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments	169	78	$ 8
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	148	70
Recoveries	14	8
Write-offs	(91)	(54)
Reserve adjustments	246	124
Ending Balance December 31,	317	148	70
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	7	4
Recoveries	1	0
Write-offs	(2)	(2)
Reserve adjustments	16	5
Ending Balance December 31,	22	7	4
CECONY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	166	73
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments	166	74	7
CECONY | Accounts receivable - customers | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	138	65
Recoveries	12	6
Write-offs	(86)	(50)
Reserve adjustments	240	117
Ending Balance December 31,	304	138	65
CECONY | Other receivables | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at January 1,	4	3
Recoveries	1	0
Write-offs	(1)	(1)
Reserve adjustments	15	2
Ending Balance December 31,	$ 19	$ 4	$ 3

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 10,000,000	$ 5,000,000	$ 13,000,000
Maximum employer contribution match (up to)	1
Amount employee contribution for employer match	9
Maximum employee investment per year (up to)	$ 25,000
Maximum percentage allowed to invest (not more than)	20.00%
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 9,000,000	4,000,000	11,000,000
Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock received upon vesting (in shares)	1
Compensation expense to be recognized	$ 33,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 8,000,000	21,000,000	24,000,000
Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 27,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 7,000,000	18,000,000	22,000,000
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period (years)	3 years
Time-based Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	1,000,000	1,000,000
Weighted average grant date price per share (in dollars per share)	$ 74.80
Time-based Awards | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	$ 1,000,000	$ 1,000,000
Weighted average grant date price per share (in dollars per share)	$ 74.80
2013 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares of common stock that can be awarded under the plan	5,000,000
TSR Portion | Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 74.46
TSR Portion | Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 74.23
Non-TSR Portion | Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 71.04
Non-TSR Portion | Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 71.25
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued (in shares)	36,000
Weighted average grant date price per share (in dollars per share)	$ 77.53
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	957,866	836,984	747,899
Weighted average share price per share, on shares purchased on open market (in dollars per share)	$ 73.38	$ 79.82	$ 85.45

Stock-Based Compensation - Stoc

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 35	$ 17	$ 47
Income tax benefit	10	5	13
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	23	7	36
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	1	2
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	2	2
Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	7	7
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	31	16	40
Income tax benefit	9	4	11
CECONY | Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	19	6	30
CECONY | Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	1	2
CECONY | Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	2	2
CECONY | Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 7	$ 7	$ 6

Stock-Based Compensation - Assu

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum	0.39%	0.10%	1.58%
Risk-free interest rate, maximum	0.73%	0.13%	1.59%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	17.25%	30.16%	12.89%
Expected share price volatility, maximum (percent)	31.42%	40.95%	15.51%

Stock-Based Compensation - Summ

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2021$ / sharesshares
Units
Non-vested at beginning of period (in shares) | shares	901,524
Granted (in shares) | shares	401,100
Vested (in shares) | shares	(301,600)
Forfeited (in shares) | shares	(16,296)
Non-vested at end of period (in shares) | shares	984,728
CECONY
Units
Non-vested at beginning of period (in shares) | shares	686,471
Granted (in shares) | shares	301,087
Vested (in shares) | shares	(227,411)
Forfeited (in shares) | shares	(15,869)
Non-vested at end of period (in shares) | shares	744,278
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 70.11
Granted (in dollars per share)	74.46
Vested (in dollars per share)	67.27
Forfeited (in dollars per share)	75.23
Non-vested at end of period (in dollars per share)	$ 72.67
Adjustment percentage used for Performance awards	50.00%
TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 70.15
Granted (in dollars per share)	74.23
Vested (in dollars per share)	66.82
Forfeited (in dollars per share)	75.21
Non-vested at end of period (in dollars per share)	72.71
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	81.83
Granted (in dollars per share)	71.04
Vested (in dollars per share)	76.37
Forfeited (in dollars per share)	79.78
Non-vested at end of period (in dollars per share)	$ 79.14
Adjustment percentage used for Performance awards	50.00%
Non-TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 81.80
Granted (in dollars per share)	71.25
Vested (in dollars per share)	76.48
Forfeited (in dollars per share)	79.84
Non-vested at end of period (in dollars per share)	$ 79.20

Stock-Based Compensation - Su_2

Stock-Based Compensation - Summary of Changes in Status of Time-Based Awards (Details) - Time-based Awards	12 Months Ended
	Dec. 31, 2021$ / sharesshares
Units
Non-vested at beginning of period (in shares) | shares	67,438
Granted (in shares) | shares	17,150
Vested (in shares) | shares	(21,121)
Forfeited (in shares) | shares	(1,847)
Non-vested at end of period (in shares) | shares	61,620
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.40
Granted (in dollars per share) | $ / shares	74.80
Vested (in dollars per share) | $ / shares	77.96
Forfeited (in dollars per share) | $ / shares	80.23
Non-vested at end of period (in dollars per share) | $ / shares	$ 79.68
CECONY
Units
Non-vested at beginning of period (in shares) | shares	62,838
Granted (in shares) | shares	16,200
Vested (in shares) | shares	(19,588)
Forfeited (in shares) | shares	(1,580)
Non-vested at end of period (in shares) | shares	57,870
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.42
Granted (in dollars per share) | $ / shares	74.80
Vested (in dollars per share) | $ / shares	77.95
Forfeited (in dollars per share) | $ / shares	79.89
Non-vested at end of period (in dollars per share) | $ / shares	$ 79.70

Financial Information by Busi_3

Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Revenues	$ 13,676	$ 12,246	$ 12,574
Depreciation and amortization	2,032	1,920	1,684
Operating income	2,826	2,654	2,676
Other Income (deductions)	(538)	(401)	51
Interest charges	905	1,019	991
Income taxes on operating income	340	193	300
Total assets	63,116	62,895	58,079
Capital expenditures	3,964	4,085	3,676
Income tax expense (benefit) on non-operating income	(150)	(103)	(4)
Parent Company
Segment Reporting Information [Line Items]
Total assets	21,620	21,499
CECONY
Segment Reporting Information [Line Items]
Revenues	11,716	10,647	10,821
Depreciation and amortization	1,705	1,598	1,373
Operating income	2,460	2,310	2,348
Other Income (deductions)	(108)	(171)	(35)
Total assets	52,655	50,967
Income tax expense (benefit) on non-operating income	(6)	(3)	(7)
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	1,022	736	857
Depreciation and amortization	231	231	226
Operating income	236	215	202
Other Income (deductions)	(10)	4	5
Interest charges	68	196	186
Income taxes on operating income	44	(43)	(58)
Total assets	6,554	6,848	6,528
Capital expenditures	298	616	248
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Revenues	4	4	4
Depreciation and amortization	1	1	1
Operating income	(16)	(8)	(6)
Other Income (deductions)	(407)	(215)	104
Interest charges	9	18	25
Income taxes on operating income	3	0	1
Total assets	249	1,348	1,618
Capital expenditures	31	3	205
Operating segment | CECONY
Segment Reporting Information [Line Items]
Revenues	11,716	10,647	10,821
Depreciation and amortization	1,705	1,598	1,373
Operating income	2,460	2,310	2,348
Other Income (deductions)	(108)	(171)	(35)
Interest charges	762	739	728
Income taxes on operating income	252	218	342
Total assets	52,655	50,967	46,557
Capital expenditures	3,418	3,246	3,020
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	8,806	8,103	8,062
Depreciation and amortization	1,286	1,214	1,053
Operating income	1,802	1,731	1,758
Other Income (deductions)	(84)	(134)	(28)
Interest charges	542	535	539
Income taxes on operating income	151	130	239
Total assets	36,260	35,673	32,988
Capital expenditures	2,189	2,080	1,851
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	2,378	2,036	2,132
Depreciation and amortization	326	294	231
Operating income	646	574	528
Other Income (deductions)	(16)	(25)	(4)
Interest charges	179	164	147
Income taxes on operating income	110	102	99
Total assets	13,748	12,678	11,090
Capital expenditures	1,126	1,044	1,078
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	532	508	627
Depreciation and amortization	93	90	89
Operating income	12	5	62
Other Income (deductions)	(8)	(12)	(3)
Interest charges	41	40	42
Income taxes on operating income	(9)	(14)	4
Total assets	2,647	2,616	2,479
Capital expenditures	103	122	91
Operating segment | O&R
Segment Reporting Information [Line Items]
Revenues	941	862	893
Depreciation and amortization	95	90	84
Operating income	150	147	139
Other Income (deductions)	(12)	(14)	(11)
Interest charges	42	41	41
Income taxes on operating income	21	21	21
Total assets	3,292	3,247	3,006
Capital expenditures	217	220	203
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Revenues	681	629	634
Depreciation and amortization	69	65	60
Operating income	100	99	98
Other Income (deductions)	(8)	(10)	(7)
Interest charges	27	26	27
Income taxes on operating income	13	13	15
Total assets	2,123	2,097	2,130
Capital expenditures	147	159	142
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Revenues	260	233	259
Depreciation and amortization	26	25	24
Operating income	50	48	41
Other Income (deductions)	(4)	(4)	(4)
Interest charges	15	15	14
Income taxes on operating income	8	8	6
Total assets	1,169	1,150	876
Capital expenditures	70	61	61
Other
Segment Reporting Information [Line Items]
Revenues	(7)	(3)	(1)
Depreciation and amortization	0	0	0
Operating income	(4)	(10)	(7)
Other Income (deductions)	(1)	(5)	(12)
Interest charges	24	25	11
Income taxes on operating income	20	(3)	(6)
Total assets	366	485	370
Capital expenditures	0	0	0
Other | O&R
Segment Reporting Information [Line Items]
Revenues	0	0	0
Depreciation and amortization	0	0	0
Operating income	0	0	0
Other Income (deductions)	0	0	0
Interest charges	0	0	0
Income taxes on operating income	0	0	0
Total assets	0	0	0
Capital expenditures	0	0	0
Inter-segment
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | CECONY
Segment Reporting Information [Line Items]
Revenues	(100)	(99)	(94)
Inter-segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	18	18	17
Inter-segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	8	7	7
Inter-segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	$ 74	$ 74	$ 70

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ (8)	$ (366)
Gross Amounts Offset	(24)	3
Net Amounts of Assets/ (Liabilities)	(32)	(363)
Margin deposits	1	3
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	25	(252)
Gross Amounts Offset	(26)	0
Net Amounts of Assets/ (Liabilities)	(1)	(252)
Margin deposits		3
Clean Energy Businesses | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Notional amount	1,031	863
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(289)	(225)
Gross Amounts Offset	137	(13)
Net Amounts of Assets/ (Liabilities)	(152)	(238)
Fair Value of Derivative Liabilities, Current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(20)	(24)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(131)	(174)
Gross Amounts Offset	43	11
Net Amounts of Assets/ (Liabilities)	(88)	(163)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(94)	(207)
Gross Amounts Offset	10	(33)
Net Amounts of Assets/ (Liabilities)	(84)	(240)
Fair Value of Derivative Liabilities, Non-current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(38)	(82)
Fair Value of Derivative Liabilities, Non-current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(50)	(114)
Gross Amounts Offset	10	9
Net Amounts of Assets/ (Liabilities)	(40)	(105)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(383)	(432)
Gross Amounts Offset	147	(46)
Net Amounts of Assets/ (Liabilities)	(236)	(478)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(181)	(288)
Gross Amounts Offset	53	20
Net Amounts of Assets/ (Liabilities)	(128)	(268)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	285	44
Gross Amounts Offset	(158)	14
Net Amounts of Assets/ (Liabilities)	127	58
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	135	20
Gross Amounts Offset	(64)	(12)
Net Amounts of Assets/ (Liabilities)	71	8
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	90	22
Gross Amounts Offset	(13)	35
Net Amounts of Assets/ (Liabilities)	77	57
Fair Value of Derivative Assets, Non-current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	71	16
Gross Amounts Offset	(15)	(8)
Net Amounts of Assets/ (Liabilities)	56	8
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	375	66
Gross Amounts Offset	(171)	49
Net Amounts of Assets/ (Liabilities)	204	115
Fair Value of Derivative Assets | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Derivative asset, noncurrent	4
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	206	36
Gross Amounts Offset	(79)	(20)
Net Amounts of Assets/ (Liabilities)	$ 127	$ 16

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 191	$ (26)
Total deferred gains/(losses)	122	(301)
Net deferred gains/(losses)	313	(327)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	78	(63)
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	18	(2)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	3	7
Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	5	(3)
Other interest expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	52	(65)
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	134	(26)
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	57	0
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	49	(63)
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	3	(201)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	70	(37)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	175	(27)
Total deferred gains/(losses)	109	(277)
Net deferred gains/(losses)	284	(304)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	5	(3)
CECONY | Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	5	(3)
CECONY | Other interest expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	124	(27)
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	51	0
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	43	(64)
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(177)
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 66	$ (36)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Dec. 31, 2021MWhMWMMBTUgal
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	26,982,370
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	42,333
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	253,195,063
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	3,696,000
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	24,646,000
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	28,800
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	235,570,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	3,696,000

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 406
Makeup of net credit exposure independent system operators	91
Makeup of net credit exposure with investment-grade counterparties	127
Makeup of net credit exposure non-investment grade/non-rated counterparties	53
Makeup of net credit exposure with commodity exchange brokers	135
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	145
Makeup of net credit exposure with investment-grade counterparties	79
Makeup of net credit exposure with commodity exchange brokers	$ 66

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Dec. 31, 2021USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 158
Collateral posted	170
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	43
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	94
Derivatives in net asset position additional collateral	5
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	66
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	121
Collateral posted	170
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	1
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 37

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ (11)
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(7)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets ransferred out of level 3	1
Derivative liabilities transferred from Level 3 to Level 2	4	$ 1
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets ransferred out of level 3	1
Derivative liabilities transferred from Level 3 to Level 2	4	1
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	832	675
Derivative liabilities	236	478
Recurring | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	728	550
Recurring | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(171)	53
Derivative liabilities	(148)	46
Recurring | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(79)	(16)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	587	450
Derivative liabilities	33	7
Recurring | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	541	426
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	399	168
Derivative liabilities	323	402
Recurring | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	265	140
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	17	4
Derivative liabilities	28	23
Recurring | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	201	118
Derivative liabilities	179	372
Recurring | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	127	19
Derivative liabilities	128	268
Recurring | Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(171)	53
Derivative liabilities	(148)	46
Recurring | Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(79)	(16)
Derivative liabilities	(53)	(19)
Recurring | Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	95	19
Derivative liabilities	33	7
Recurring | Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	67	15
Derivative liabilities	1	3
Recurring | Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	260	42
Derivative liabilities	266	296
Recurring | Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	138	20
Derivative liabilities	172	274
Recurring | Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	17	4
Derivative liabilities	28	23
Recurring | Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Derivative liabilities	8	10
Recurring | Interest Rate Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4
Derivative liabilities	57	106
Recurring | Interest Rate Swaps | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Interest Rate Swaps | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Interest Rate Swaps | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4
Derivative liabilities	57	106
Recurring | Interest Rate Swaps | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	627	557
Recurring | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	601	531
Recurring | Other | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	492	431
Recurring | Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	474	411
Recurring | Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	135	126
Recurring | Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	127	120
Recurring | Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Commodity Derivatives (Details) - Level 3 $ in Millions	Dec. 31, 2021USD ($)$ / kW-month$ / MWh
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (11)
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(7)
Electricity | Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (6)
Electricity | Forward Energy Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	18.75
Electricity | Forward Energy Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	82.40
Electricity | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (10)
Electricity | Forward Capacity Prices | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (8)
Electricity | Forward Capacity Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.31
Electricity | Forward Capacity Prices | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	1.35
Electricity | Forward Capacity Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	12.93
Electricity | Forward Capacity Prices | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	12.93
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 5
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	(20.27)
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.52
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	83.04
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	3.63

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (19)	$ (16)
Included in earnings	(9)	(10)
Included in regulatory assets and liabilities	3	(7)
Purchases	6	0
Settlements	5	15
Transfer out of level 3	3	(1)
Ending Balance	(11)	(19)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	(10)	(6)
Included in earnings	(3)	(5)
Included in regulatory assets and liabilities	1	(4)
Purchases	0	0
Settlements	3	6
Transfer out of level 3	2	(1)
Ending Balance	$ (7)	$ (10)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Clean Energy Businesses | Non-utility revenue
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities	$ 2	$ (3)

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Jun. 30, 2021
Variable Interest Entity [Line Items]
Noncontrolling interest	$ 299	$ 218
Clean Energy Businesses
Variable Interest Entity [Line Items]
Equity method investment			$ 11
Loss from the project, pre-tax	11
Loss from the project, after-tax	8
Tax Equity Investors
Variable Interest Entity [Line Items]
Noncontrolling interest	95
Tax Equity Projects | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)	(30)	(6)
Income (loss), after tax	(24)	(4)
Tax Equity Projects | Tax Equity Investors | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)	6	43
Income (loss), after tax	4	$ 32
CED Nevada Virginia | Con Edison Development
Variable Interest Entity [Line Items]
Loss from the project, pre-tax	155
Loss from the project, after-tax	117
CED Nevada Virginia | Tax Equity Investors
Variable Interest Entity [Line Items]
Loss from the project, pre-tax	158
Loss from the project, after-tax	$ 119

Variable Interest Entities - Ne

Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Business Acquisition [Line Items]
Noncontrolling interest	$ 299	$ 218
Great Valley Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	275	284
Other assets	37	39
Total assets	312	323
Other liabilities	14	13
Total liabilities	14	13
Accumulated depreciation	26	18
Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	431	446
Other assets	167	176
Total assets	598	622
Other liabilities	74	71
Total liabilities	74	71
Accumulated depreciation	44	30
CED Nevada Virginia
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	643
Other assets	55
Total assets	698
Other liabilities	315
Total liabilities	315
Accumulated depreciation	10
Tax Equity Investors
Business Acquisition [Line Items]
Noncontrolling interest	95
Tax Equity Investors | Great Valley Solar
Business Acquisition [Line Items]
Noncontrolling interest	84	82
Tax Equity Investors | Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Noncontrolling interest	$ 118	$ 134

Variable Interest Entities - Su

Variable Interest Entities - Summary of VIEs (Details) - Variable Interest Entity, Not Primary Beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)MW
Great Valley Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	200
Maximum Exposure to Loss | $	$ 214
Great Valley Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	15 years
Great Valley Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	344
Maximum Exposure to Loss | $	$ 406
Copper Mountain Solar - Mesquite Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	25 years
CED Nevada Virginia
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	431
Maximum Exposure to Loss | $	$ 288
CED Nevada Virginia | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
CED Nevada Virginia | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	25 years

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	$ 577	$ 576
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	58	191
Asset retirement obligations, accretion expense	18	16
Asset retirement obligations, liabilities settled	75	56
Asset retirement obligations, reductions	87	49
CECONY
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	504	508
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	55	186
Asset retirement obligations, accretion expense	15	13
Asset retirement obligations, liabilities settled	74	53
Asset retirement obligations, reductions	$ 85	$ 49

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) MMBTU in Thousands	12 Months Ended
	Dec. 31, 2021USD ($)MMBTU	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Related Party Transaction [Line Items]
Net assets	$ 20,037,000,000	$ 18,847,000,000
CECONY
Related Party Transaction [Line Items]
Net assets	16,312,000,000	14,849,000,000	$ 14,147,000,000	$ 12,910,000,000
Sale of natural gas	90,000,000	59,000,000	71,000,000
Funding limit of CECONY to O&R (not to exceed)	$ 250,000,000
CECONY | Related Party, Lending of Funds
Related Party Transaction [Line Items]
Lending period (not more than) (months)	12 months
CECONY | Equity Method Investee | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Amount of transaction	$ 0	0
Contract term (years)	20 years
Generating capacity per day (in dekatherms) | MMBTU	250
CECONY | Equity Method Investee | Stagecoach | Purchased Power Costs
Related Party Transaction [Line Items]
Amount of transaction	$ 31,000,000	34,000,000	$ 33,000,000
CECONY | Affiliated Entity | Financial Electric Capacity Contract | Con Edison Energy
Related Party Transaction [Line Items]
Loss on financial electric capacity contracts	(4,000,000)
O&R
Related Party Transaction [Line Items]
Net assets	888,000,000
Outstanding loans	$ 0	$ 0
CET Electric | NY Transco
Related Party Transaction [Line Items]
Ownership interest, percentage	45.70%
Amounts billed	$ 5,900,000
CET Gas | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Percentage of equity interest owned	10.20%	11.30%
Expected reduction in equity interest	8.50%

Related Party Transactions - Su

Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Cost of services provided	$ 137	$ 128	$ 121
Cost of services received	$ 68	$ 66	$ 64

Dispositions (Details)

Dispositions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold	$ 44,214			$ 42,024
Stagecoach
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investment		$ 630	$ 667
Clean Energy Businesses | Subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold		$ 192
Gain (loss) on sale of projects	3
Gain on sale, after tax	2
Equity method investment	11
Con Edison Transmission | Subsidiaries | Stagecoach
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	1,225
CET Gas | Subsidiaries | Stagecoach
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 629

Schedule I - Condensed Financ_2

Schedule I - Condensed Financial Information - Income and Comprehensive Income (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Income Statements,Captions [Line Items]
Interest expense	$ (905)	$ (1,019)	$ (991)
NET INCOME FOR COMMON STOCK	1,346	1,101	1,343
Comprehensive Income	$ 1,376	$ 1,095	$ 1,340
Net Income Per Share – Basic (in dollars per share)	$ 3.86	$ 3.29	$ 4.09
Net Income Per Share – Diluted (in dollars per share)	$ 3.85	$ 3.28	$ 4.08
Average Number Of Shares Outstanding—Basic (in shares)	348.4	334.8	328.5
Average Number Of Shares Outstanding—Diluted (in shares)	349.4	335.7	329.5
Parent Company
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,369	$ 1,105	$ 1,354
Other income (deductions), net of taxes	14	56	76
Interest expense	(37)	(60)	(87)
NET INCOME FOR COMMON STOCK	1,346	1,101	1,343
Comprehensive Income	$ 1,376	$ 1,095	$ 1,340
Net Income Per Share – Basic (in dollars per share)	$ 3.86	$ 3.29	$ 4.09
Net Income Per Share – Diluted (in dollars per share)	3.85	3.28	4.08
Dividends Declared Per Share (in dollars per share)	$ 3.10	$ 3.06	$ 2.96
Average Number Of Shares Outstanding—Basic (in shares)	348.4	334.8	328.5
Average Number Of Shares Outstanding—Diluted (in shares)	349.4	335.7	329.5

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information - Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	$ 1,346	$ 1,101	$ 1,343
Change in Assets:
Taxes receivable	13	(6)	29
Other – net (b)	(103)	(134)	54
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,733	2,198	3,134
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,484)	(4,224)	(3,782)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(382)	178	(874)
Issuance of long-term debt	2,804	2,925	3,017
Retirement of long-term debt	(1,960)	(518)	(1,195)
Debt issuance costs	(40)	(47)	(32)
Issuance of common shares for stock plans	60	58	54
Issuance of common shares - public offering	775	640	825
Common stock dividends	(1,030)	(975)	(924)
NET CASH FLOWS FROM FINANCING ACTIVITIES	461	2,245	859
NET CHANGE FOR THE PERIOD	(290)	219	211
BALANCE AT BEGINNING OF PERIOD	1,436	1,217	1,006
BALANCE AT END OF PERIOD	1,146	1,436	1,217
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,344	1,185	1,250
Change in Assets:
Other – net (b)	(85)	(49)	54
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,186	1,693	2,502
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,729)	(3,416)	(3,124)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(299)	523	(55)
Issuance of long-term debt	2,250	2,200	1,300
Retirement of long-term debt	(640)	(350)	(475)
Debt issuance costs	(27)	(34)	(21)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,396	1,857	737
NET CHANGE FOR THE PERIOD	(147)	134	115
BALANCE AT BEGINNING OF PERIOD	1,067	933	818
BALANCE AT END OF PERIOD	920	1,067	933
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,346	1,101	1,343
Equity in earnings of subsidiaries	(1,369)	(1,105)	(1,354)
Change in Assets:
Special deposits	0	0	(3)
Taxes receivable	15		25
Other – net (b)	211	(521)	44
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,459	538	1,029
INVESTING ACTIVITIES
Contributions to subsidiaries	(1,135)	(626)	(930)
Debt receivable from affiliated companies	875	400	450
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(260)	(226)	(480)
FINANCING ACTIVITIES
Net proceeds of short-term debt	50	(537)	(783)
Issuance of long-term debt	0	650	825
Retirement of long-term debt	(1,178)	(3)	(553)
Debt issuance costs	(1)	(3)	0
Issuance of common shares for stock plans	60	58	54
Issuance of common shares - public offering	775	640	825
Common stock dividends	(1,030)	(975)	(924)
NET CASH FLOWS FROM FINANCING ACTIVITIES	(1,324)	(170)	(556)
NET CHANGE FOR THE PERIOD	(125)	142	(7)
BALANCE AT BEGINNING OF PERIOD	144	2	9
BALANCE AT END OF PERIOD	19	144	2
Parent Company | Revision of Prior Period, Adjustment
FINANCING ACTIVITIES
Retirement of long-term debt	(1,175)
Parent Company | CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	988	982	912
Parent Company | O&R
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	52	49	47
Parent Company | Clean Energy Businesses
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	64	21	3
Parent Company | Con Edison Transmission
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	$ 152	$ 11	$ 12

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current Assets
Cash and temporary cash investments	$ 992	$ 1,272
Accounts receivable - customers, less allowance for uncollectible accounts	1,943	1,701
Taxes receivable	13	26
Prepayments	295	271
Other current assets	361	231
TOTAL CURRENT ASSETS	5,551	5,301
Investments in subsidiaries and others	853	1,816
Goodwill	439	446
Other noncurrent assets	8,116	9,223
TOTAL ASSETS	63,116	62,895	$ 58,079
Current Liabilities
Long-term debt due within one year		1,967
Term Loan	0	165
Notes payable	1,488	1,705
Accounts payable	1,497	1,475
Accrued taxes	104	150
Other current liabilities	461	426
TOTAL CURRENT LIABILITIES	5,427	7,354
Long-term debt	22,604	20,382
Shareholders’ Equity
Equity	20,037	18,847
TOTAL LIABILITIES AND EQUITY	63,116	62,895
Parent Company
Current Assets
Cash and temporary cash investments	19	144
Accounts receivable - customers, less allowance for uncollectible accounts	0	1
Taxes receivable	3	18
Accounts receivable from affiliated companies	1,199	1,256
Prepayments	28	62
Other current assets	14	12
TOTAL CURRENT ASSETS	1,263	1,493
Investments in subsidiaries and others	19,951	18,670
Goodwill	406	406
Deferred income tax	0	55
Long-term debt receivable from affiliated companies	0	875
TOTAL ASSETS	21,620	21,499
Current Liabilities
Long-term debt due within one year	293	1,178
Notes payable	50	0
Accounts payable	1	0
Accounts payable to affiliated companies	517	517
Accrued taxes	2	6
Other current liabilities	9	12
TOTAL CURRENT LIABILITIES	872	1,713
Deferred income tax	64	0
Total Liabilities	936	1,713
Long-term debt	647	939
Shareholders’ Equity
Common stock, including additional paid-in capital	9,748	8,844
Retained earnings	10,289	10,003
Equity	20,037	18,847
TOTAL LIABILITIES AND EQUITY	$ 21,620	$ 21,499

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - Allowance For Uncollectible Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 154	$ 74	$ 68
Charged To Costs And Expenses	83	72	77
Charged To Other Accounts	0	0	0
Deductions	102	8	(71)
Balance At End of Period	339	154	74
CECONY
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	143	68	61
Charged To Costs And Expenses	78	65	72
Charged To Other Accounts	0	0	0
Deductions	102	10	(65)
Balance At End of Period	$ 323	$ 143	$ 68